47967129 Manual Pipephase

PIPEPHASE 9.3 Keyword Manual

PIPEPHASE 9.3Keyword Manual

The software described in this document is furnished under a written agreement and may be used only in accordance with the terms and conditions of the license agreement under which you obtained it. The technical documentation is delivered to you AS IS and Invensys Systems, Inc. makes no warranty as to its accuracy or use. Any use of the technical documentation or the information contained therein is at the risk of the user. Documentation may include technical or other inaccuracies or typographical errors. Invensys Systems, Inc. reserves the right to make changes without prior notices.

Copyright Notice © 2009 Invensys Systems, Inc. All rights reserved. No part of the material protected by this copyright may be reproduced or utilized in any form or by any means, electronic or mechanical, including photocopying, recording, broadcasting, or by any information storage and retrieval system without permission in writing from Invensys Systems, Inc.

Trademarks PIPEPHASE, NETOPT, NETOPT, Invensys, SIMSCI-ESSCOR, and SIM4ME are trademarks of Invensys plc., its subsidiaries, and affiliates.

TACITE is a trademark of Institut Francais du Petrole (IFP).

OLGAS 1.1, OLGAS TWO-PHASE, and OLGAS THREE-PHASE are trademarks of SCANDPOWER A/S.

FLEXlm is a trademark of Macrovision Corporation.

Windows VISTA, Windows XP, Windows 2003 Server, Windows 2008 Server, Microsoft Office, and MS-DOS are trademarks of Microsoft Corporation.

Pentium and Visual Fortran is a trademark of Intel Corporation.

Adobe, Acrobat, Exchange, and Reader are registered marks and/or trademarks of Adobe Systems, Inc.

All other products noted herein are trademarks of their respective companies.

U.S. GOVERNMENT RESTRICTED RIGHTS LEGEND

The Software and accompanying written materials are provided with restricted rights. Use, duplication, or disclosure by the Government is subject to restrictions as set forth in subparagraph (c) (1) (ii) of the Rights in Technical Data and Computer Software clause at DFARS 252.227-7013 or in subparagraphs (c) (1) and (2) of the Commercial Computer Software – Restricted Rights clause at 48 C.F.R 52.227-19, as applicable. The Contractor/Manufacturer is: Invensys Systems, Inc. (a division of Invensys plc. and owner of the SimSci-Esscor brand) 26561 Rancho Parkway South, Lake Forest, CA 92630, USA.

Printed in the United States of America, May 2009

Table of Contents

Chapter 1 IntroductionAbout This Manual . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-1

New Users . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-2Occasional Users . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-2Experienced Users . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-2

About SimSci-Esscor . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-2Support Services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-2

Chapter 2 OverviewAbout This Chapter. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-2Scope and Objectives of PIPEPHASE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-2

Flow Devices . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-3Property Data. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-3Calculation Modes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-3Piping Systems . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-3Pressure Drop Methods . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-4User Convenience . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-4

Typical Applications of PIPEPHASE. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-4Field Production . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-4Transmission Pipelines . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-5Slug Catcher Sizing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-6

Solving Networks with PIPEPHASE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-6Links . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-7Networks . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-7The Building Blocks . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-8Joining Segments Together . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-8Joining Links Together . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-9Pressure Balance Solution Method . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-9

PIPEPHASE Keyword Manual TOC-1

Chapter 3 Using PIPEPHASEAbout This Chapter . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-3Defining the Application . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-3

Properties of Fluid Types . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-3Flows and Conditions of Fluids . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-4Sphering . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-4Piping Structure. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-4What PIPEPHASE Calculates. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-4Rating, Design, Case Studies and Nodal Analysis . . . . . . . . . . . . . . . . . . . . . . . .3-5

Global Settings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-5Units of Measurement . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-5Printout Options . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-6Defaults . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-7

Defining Fluid Properties . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-8Defining Properties for Compositional Fluids . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-8

Water as a Special Component . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-9Library Components . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-9Non-library Components. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-10Petroleum Pseudocomponents. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-10Assay Curve . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-11Additional Component Capabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-11Thermodynamic Properties and Phase Separation . . . . . . . . . . . . . . . . . . . . . . . .3-12Transport properties . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-13Tabular Data for Compositional Fluids. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-14Multiple Thermodynamic Methods. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-15Additional Thermodynamic Capabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-15

Defining Properties for Non-Compositional Fluids . . . . . . . . . . . . . . . . . . . . . . . . . . .3-16Liquid . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-17Gas. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-17Steam. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-18Gas Condensate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-18Blackoil . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-19

Defining Properties for Mixed Compositional/Non-Compositional Fluids . . . . . . . . .3-20Generating and Using Tables of Properties . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-20Sources . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-21

Compositional Sources . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-21Non-Compositional Sources . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-21

Structure of Network Systems . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-22Controlling Convergence of Networks (PBAL) . . . . . . . . . . . . . . . . . . . . . . . . . .3-22Networks . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-23

PIPEPHASE Flow and Equipment Devices. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-24Flow Devices (have length). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-24Equipment Devices (have no length) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-25Fittings. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-25Process Equipment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-25Unit Operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-26Flow Device Sizing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-26

TOC-2 Table of Contents

Pressure Drop Calculations. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-27Pressure Drop in Flow Devices . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-28Nominal Diameter and Pipe Schedule. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-30Pressure Drop in Completions. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-31Pressure Drop in Fittings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-32

Equipment Items . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-34Heat Transfer Calculations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-37

Detailed Heat Transfer in Pipe and Tubing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-38Gaslift Analysis. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-39Sphering or Pigging . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-40Reservoirs and Inflow Performance Relationships. . . . . . . . . . . . . . . . . . . . . . . . . . . 3-40Production Planning and Time-Stepping . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-41

Time Changes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-41Wells and Well Grouping . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-41Reservoir Depletion. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-42Facilities Planning . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-42

Subsurface Networks and Multiple Completion Modeling . . . . . . . . . . . . . . . . . . . . 3-43A Single Well . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-43More Than One Well . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-44Multiple Completions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-44

Case Studies . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-45Global Changes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-46Individual Changes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-46

Nodal Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-47Dividing the Link. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-47Selecting Parameters and Flowrates . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-47Sensitivity Results . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-47Grouping Parameters . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-48

Chapter 4 Input ReferenceAbout This Chapter. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-6Categories of Input . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-7

Order of Categories . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-7Keywords . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-8

Keyword Input. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-8Qualifiers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-8Commenting Input . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-9Default Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-9Units of Measurement. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-10

Basis of Measurements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-10Multiple Units of Measurement. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-10Continuing Statements. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-11Layout of Input . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-11

Input Statement Descriptions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-11Legend . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-11

GENERAL Data Category of Input . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-13Global Parameters . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-13

Keyword Manual TOC-3

TITLE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-14DESCRIPTION. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-14DIMENSION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-14CALCULATION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-20FCODE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-21DEFAULT. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-24SEGMENT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-26LIMITS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-28PRINT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-28OUTDIMENSION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-31

COMPONENT Data Category of Input . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-32Overview . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-32COMPONENT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-33LIBID . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-34PETROLEUM. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-34ASSAY . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-35CUTPOINTS. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-37MW . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-37SPGR. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-37API . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-37ACENTRIC. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-37ZC . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-37TC() . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-37PC() . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-37NBP() . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-37STDDENSITY() . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-37VC . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-38VP() . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-38ENTHALPY() . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-38CP() . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-38LATENT(). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-38DENSITY() . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-38VISCOSITY() . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-38CONDUCTIVITY() . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-38SURFACE() . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-38

NETWORK Data Category of Input . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-40Overview . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-40NETWORK. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-40SOLUTION. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-40TOLERANCE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-44ACCELERATION (for PBAL Network Method Only) . . . . . . . . . . . . . . . . . . . .4-44

THERMODYNAMIC Data Category of Input . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-46Overview . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-46THERMODYNAMIC. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-48METHOD . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-48WATER. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-52BWRS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-53LKP . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-53


PR . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-53SRK . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-53

PVT Data Category of Input. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-54Overview . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-54PVT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-54SET . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-54SET for Non-Compositional Liquid . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-55SET for Non-Compositional Gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-55SET for Steam . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-55SET for Compositional Fluid . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-56SET for Condensate. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-56SET for Compositional Blackoil (Compositional sets only) . . . . . . . . . . . . . . . . 4-57SET for Blackoil . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-57ADJUST (Blackoil only) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-58LIFTGAS (Blackoil only) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-59TABULAR (Blackoil only) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-59FVF (Blackoil only). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-60SGOR() (Blackoil only). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-61VISCOSITY() (Blackoil only) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-61GRAVITY() (Blackoil only) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-61CORRELATION. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-62DIMENSION. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-64GENERATE (for Compositional) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-65GENERATE (for Blackoil) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-66FILE. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-70FILE (for Blackoil) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-70

STRUCTURE Data Category of Input . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-71Overview . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-71STRUCTURE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-75System Nodes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-75SOURCE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-75CSOURCE. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-78WTEST . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-80Distillation Data. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-81Gravity Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-82Molecular Weight . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-83LIGHTENDS. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-83SINK . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-87JUNCTION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-88LINK . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-89Flow Devices (have length). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-92PIPE. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-92ANNULUS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-94TUBING . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-95Dual Completions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-98Parallel Dual Completions. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-99Equipment Devices (have no length). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-101COMPLETION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-101


COMPRESSOR . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-102MCOMPRESS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-103COOLER. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-105DPDT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-105EXPANDER . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-106GLVALVE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-107HEATER . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-107INJECTION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-108IPR. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-109PUMP . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-119REGULATOR. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-121SEPARATOR . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-122BEND . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-124CHECK . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-125CHOKE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-125MCHOKE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-127MREGULATOR . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-128CONTRACTION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-128ENTRANCE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-129EXIT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-130EXPANSION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-131NOZZLE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-132ORIFICE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-133TEE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-133VALVE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-134VENTURIMETER . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-136

UNIT OPERATIONS Data Category of Input. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-137Overview . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-137UNIT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-138CALCULATOR . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-138DIMENSION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-139HYDRATES . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-144EVALUATE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-145

GASLIFT Category of Input . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-146Overview . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-146

SIZING DATA Category of Input . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-150Overview . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-150SIZING . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-150DEVICE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-150LINE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-150MAXV. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-151

TIME-STEPPING Data Category of Input . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-152TIMESTEPPING . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-152CHANGE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-152

CASE STUDY Data Category of Input . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-153Overview . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-153CASESTUDY . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-154DESCRIPTION. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-154


RESTORE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-154PARAMETER. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-154Sources. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-155Sinks . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-159Junctions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-163Pipe . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-167Tubing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-168Annulus . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-169Compressors . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-170Pumps . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-170Heater. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-171Cooler . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-171Completion . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-172Gaslift Valves . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-172Chokes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-172Separators . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-173Regulators . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-174Expanders . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-175Valves . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-175Injection . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-176DPDT Device . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-176MCOMP . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-177Bend. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-177Check Valve . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-178Contraction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-179Entrance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-179Exit. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-179Expansion . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-180Nozzle . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-180Orifice . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-181Tee . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-181IPR. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-182Calculator Unit . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-182Optimization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-183Objective Parameter . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-183Constraint Variable . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-184Decision Variable . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-184PVT Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-185Network Data. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-185LINK . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-186

SENSITIVITY ANALYSIS Data Category of Input . . . . . . . . . . . . . . . . . . . . . . . . . 4-189Overview . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-189SENSITIVITY. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-189NODE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-189DESCRIPTION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-190INFLOW . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-190OUTFLOW . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-193FLOW . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-193


PSPLIT Data Category of Input . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-194PSPLIT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-194TABLE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-194

User-Defined DP Correlations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-195FORTRAN Standards . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-195User Subroutine Specifications . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-196Saving Data for Output . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-199PIPEPHASE Flash Routine Interface . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-200Moody Friction Factor Interface . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-201Examples . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-201

User-Defined Viscosity Correlation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-206Implementing the Correlation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-206User Subroutine Specifications . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-206Common Blocks . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-207

Inflow Performance Relationship (IPR). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-211User-Defined IPR . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-211Built-in Variable List . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-211Keyword Input. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-211Subprogram Structure . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-212Common Blocks . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-212Data Extraction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-213Units Conversion Utility . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-213Calculation Utilities. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-214Secondary Output Utility . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-215Example Implementation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-215Variables and Arrays for User-Defined IPR Models . . . . . . . . . . . . . . . . . . . . . .4-217

Chapter 5 ResultsAbout This Chapter . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-2Report Options . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-3Description of Reports . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-3

Input Reprint . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-3Intermediate Printout. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-4Solution Output . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-4

Input Reprint Examples . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-8Thermodynamic Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-8Component Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-8General Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-9PVT Data. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-10Network Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-11Source Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-11Structure Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-12Network Connectivity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-13Case Study. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-13Sizing Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-14Nodal Analysis (Sensitivity) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-15Lift Gas Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-15


PVTGEN Results . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-16Intermediate PRINTOUT Example . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-17

Network Directory. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-17Inflow Performance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-18

Solution Output Examples . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-19Flash Report. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-19Separator Report . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-20Link Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-20Node Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-21Device Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-21Structure Data Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-22Velocity Summary. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-22Results Summary. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-23Link Device Detail Report. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-23Pressure and Temperature Report . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-24Pressure and Temperature Plots . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-25Phase Envelope Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-26Phase Envelope Plot . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-27Holdup and Velocity Report . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-28Pressure Gradient Detail Report . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-29Taitel-Dukler-Barnea Flow Regime Map . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-30Link Property Detail Report . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-30Viscosity and Density Results . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-31Friction and Surface Tension Results . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-31Heat Transfer Calculations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-32Slug Report . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-33Case Summary. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-34Nodal Analysis (Sensitivity) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-35Sphering Report . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-37Results Access System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-38

Chapter 6 Technical ReferenceAbout This Chapter. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-4An Introduction to Fluid Flow . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-4

Basic Fluid Flow Theory . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-4The Steady State Flow Process — Single-Phase Fluids . . . . . . . . . . . . . . . . . . . 6-5Laminar and Turbulent Single-phase Flow . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-9Laminar and Transitional Flow Inside Pipes. . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-10Critical Flow - A Qualitative Description . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-21

Recommendations on Pressure Drop Correlations . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-27Solution Algorithms Used in PIPEPHASE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-27

The Calculation Segment and Iteration Methodology. . . . . . . . . . . . . . . . . . . . . 6-27The Network Calculation Method . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-33

Fluid Models Used in PIPEPHASE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-36Non-Compositional Fluid Models . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-36Condensate. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-47Steam Model . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-47


Compositional Fluid Models. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-48Heat Transfer in Flow Devices. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-51

Heat Transfer for Non-Compositional Fluids . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-52Heat Transfer for Compositional Fluids . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-52The Overall Heat Transfer Coefficient (U-value) . . . . . . . . . . . . . . . . . . . . . . . . .6-54

Equipment & Fittings Flow Devices . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-58Electrical Submersible Pump (ESP) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-59Compressor . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-59DPDT Devices. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-60Chokes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-60Check Valves. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-65Heaters and Coolers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-65Separators . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-66Fittings. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-66

Converging Network Simulations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-72User Requirements for this Section. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-72General Recommendations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-73Specific Recommendations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-75

Sub-Network Algorithm. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-95Introduction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-95

Frequently Asked Questions. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-96Data Transfer System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-111

Procedure for Accessing PRO/II Stream Data . . . . . . . . . . . . . . . . . . . . . . . . . . .6-111

Chapter 7 Component Data SummaryAbout This Chapter . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-1

General Information . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-1PRO/II Component Library. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-1Non-Library Components . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-2Petroleum Components . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-2Solid Components . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-2Component Properties . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-2UNIFAC Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-2COMPONENT DATA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-3

Chapter 8 Thermodynamic Data SummaryAbout This Chapter . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .8-1

The METHOD Statement (required) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .8-1Method-Specific Water Handling Options (optional - Section 2.1.6). . . . . . . . . .8-3Property Statements (optional). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .8-3User-Supplied K-value Data (optional - Section 2.3.12) . . . . . . . . . . . . . . . . . . .8-5Binary Interaction Data (optional) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .8-5Liquid Phase Activity Binary Interaction Data (Section 2.5) . . . . . . . . . . . . . . .8-6Other Binary Data For Liquid Activity Methods (Section 2.5) . . . . . . . . . . . . . .8-7Pure Component Alpha Formulations (optional - Section 2.4.5). . . . . . . . . . . . .8-8


Appendix A Pressure Drop CorrelationsRecommendations on Pressure Drop Correlations . . . . . . . . . . . . . . . . . . . . . . . . . . . A-2

Single-Phase Methods . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . A-2Two-Phase and Compositional Methods. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . A-2

General Guidelines on Correlation Selection . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . A-16

Appendix B GlossaryGlossary of Frequently Used Terms . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . B-1

Appendix C ReferencesBibliography . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . C-1

Appendix D Default Values of Schedule Pipe SizesSteel Pipe Wall Thicknesses Used by INPLANT. . . . . . . . . . . . . . . . . . . . . . . . . . . . D-1

Appendix E User-Definable Nominal Pipe SizesFormat for User-Created NPS Database. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . E-1



Chapter 1 Introduction

About This Manual

This manual describes the capabilities and use of the PIPEPHASE program and is designed to help you gain maximum utility out of the program. It can be used with all DOS and Windows versions of PIPEPHASE. This manual contains the chapters listed in Table 1-1, an appendix of pressure drop correlations, a glossary, a bibliographical reference, and an index.

Table 1-1: Quick Reference for New, Occasional and Experienced UsersSee… Which… If you are a…

Chapter 1, Introduction Introduces the manual, the program, and SimSci-Esscor.

New User

Chapter 2, Overview Explains the main concepts of piping and network analysis and the applications the program can solve.

New User

Chapter 3, Using PIPEPHASE

Describes the data needed to run the program, the way it uses the data, and how you can use the program.

New or Occasional User

Chapter 4, Input Reference Provides statement-by-statement descriptions of program input.

New, Occasional or Experienced User

Chapter 5, Results Provides a detailed description of and commentary on program output.


Chapter 6, Technical Reference

Provides detailed background information to models used in the program.


Chapter 7, Component Data Summary

Provides an overview of the Component Data Category.


Chapter 8, Thermodynamic Data Summary

Provides an overview of the Thermodynamic Data Category.


PIPEPHASE Keyword Manual 1-1

New Users

If you are an engineer new to PIPEPHASE, this manual will tell you what the program does and how to use it. Chapter 2, Overview, describes the scope of the program, the concepts involved in pipeline pressure drop analyses and how PIPEPHASE tackles them.

Chapter 3, Using PIPEPHASE, describes the data that the program needs, the conventions to follow in inputting the data to the program, and what the program will produce as output. It then describes all the capabilities of the program and how to invoke them, with signposts given to guide you through Chapter 4, Input Reference.

Note: If you read nothing else, read Chapter 3, Using PIPEPHASE.

Chapter 5, Results, is a guided tour of the results output and how to interpret the output.

Chapter 6, Technical Reference, gives more detailed information on methodologies used in the program calculations

Occasional Users

If you are an occasional user revisiting PIPEPHASE after an absence, take some time to skim through Chapter 3, Using PIPEPHASE, to remind yourself of the program’s capabilities and conventions. Then go on to Chapter 4, Input Reference.

Experienced Users

If you use PIPEPHASE regularly, you will be able to find everything you need in Chapter 4, Input Reference, and Chapter 6, Technical Reference.

About SimSci-Esscor

PIPEPHASE is backed by the full resources of SimSci-Esscor. SimSci-Esscor provides the most thorough service capabilities and advanced process modeling technologies available to the process industries. SimSci-Esscor’s comprehensive support around the world, allied with its training seminars for every level of user, is aimed solely at making your use of PIPEPHASE the most efficient and effective that it can be.

Support Services

Both new and experienced users will benefit significantly from attending one of SimSci-Esscor’s regularly scheduled training courses on PIPEPHASE. If you would like to obtain a list of available courses, or if you have any questions relating to the use of PIPEPHASE, its methods, data, or technology, please call your nearest SimSci-Esscor support office.

1-2 Introduction

To contact your nearest SimSci-Esscor support office, select and click Technical Support...from the Help menu. A Help desk page is displayed. Click the Support Centres link to view the contact details of your nearest support centre. The SimSci-Esscor support centres are also hosted on our website. Please visit the following link: http://www.simsci-esscor.com/us/eng/support/supportlocations/default.htm


http://www.simsci-esscor.com/us/eng/support/supportlocations/default.htm



This Page Intentionally Blank

Chapter 2 Overview

Chapter Contents

About This Chapter . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2Scope and Objectives of PIPEPHASE. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2

Flow Devices . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3Property Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3Calculation Modes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3Piping Systems . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3Pressure Drop Methods. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4User Convenience . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4

Typical Applications of PIPEPHASE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4Field Production . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4Transmission Pipelines . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5Slug Catcher Sizing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6

Solving Networks with PIPEPHASE. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6Links . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7Networks. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7The Building Blocks . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8Joining Segments Together. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8Joining Links Together . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9Pressure Balance Solution Method . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9


About This Chapter

This chapter describes the scope, objectives, applications and capabilities of PIPEPHASE. It introduces the concepts involved in pipeline, well, and network analysis and describes how PIPEPHASE tackles them. This chapter should be read by anyone new to PIPEPHASE.

Scope and Objectives of PIPEPHASE

PIPEPHASE is a simulation program which predicts steady-state pressure, temperature, and liquid holdup profiles in wells, flowlines, gathering systems, and other linear or network configurations of pipes, wells, pumps, compressors, separators, and other facilities. The fluid types that PIPEPHASE can handle include liquid, gas, steam, and multiphase mixtures of gas and liquid.

Figure 2-1: Scope of PIPEPHASE Application

Several special capabilities have also been designed into PIPEPHASE including well analysis with inflow performance; gas lift analysis; pipeline sphering; and sensitivity (nodal) analysis. These additions extend the range of the PIPEPHASE application so that the full range of pipeline and piping network problems can be solved.

Special capabilities have been designed into PIPEPHASE like pipeline sphering. This extends the range of PIPEPHASE applications so that varied pipeline and piping network problems can be solved.

2-2 Overview

Flow Devices

PIPEPHASE can be used for simulating single or multiphase fluid flow through any combination of pipes, tubing, annuli, fittings and items of process equipment. In PIPEPHASE, pipes, tubing and annuli are collectively known as flow devices. Pipes are normally used for modeling pipelines whereas tubing and annuli simulate flow in wells. A complete listing of available flow devices can be found in This chapter describes how PIPEPHASE handles flow devices within pipe sections.

Property Data

PIPEPHASE can simulate fluids defined either by composition, by assay (ASTM, TBP) curve, or by non-compositional means. For compositionally or assay defined fluids, all component, thermodynamic, and transport property data are stored in, or created from, PIPEPHASE’s data and calculation libraries. For non-compositionally defined fluids, PIPEPHASE uses built-in correlations to determine all physical property data the program requires for pressure drop and heat transfer calculations. Details of the different fluid types and how to define them can be found in Chapter 3, Using PIPEPHASE.

Calculation Modes

PIPEPHASE can be used for designing new systems or rating existing ones. Any piping topology can be addressed, from a simple single link of flow devices to the most complex network of pipelines and wells, including multiple inlets and outlets and any degree of looping. In network configurations, you are allowed to fix almost any combination of pressures and flowrates and PIPEPHASE will solve for all the remaining unknowns.

Piping Systems

PIPEPHASE rigorously simulates anything from a simple single pipe to the most complex piping systems with multiple inlets and outlets. Line capacities, flow distribution in loops, heat transfer effects, Joule-Thomson effects, in-line flow patterns, vapor and liquid velocities, and preferential phase splitting at tees for steam systems are all accurately determined. Details of how these are invoked can be found in Chapter 3, Using PIPEPHASE.

Line capacities, flow distribution in loops, heat transfer effects, Joule-Thomson effects, in-line flow patterns, vapor and liquid velocities and preferential phase splitting at tees for steam systems are all accurately determined. Details of how these are invoked can be found in Chapter 3, Using PIPEPHASE.


Pressure Drop Methods

PIPEPHASE solves pressure drop and energy balance equations, while simultaneously performing rigorous heat transfer calculations. You can choose from more than twenty industry-standard correlations for predicting the pressure drop and liquid holdup. A full list of correlations is in Chapter 4, Input Reference, Tables 4-6a – 4-6c and 4-7.

User Convenience

PIPEPHASE is fully supported by SimSci-Esscor’s experienced staff who can supply advise on using the program and offer assistance if you are having problems. Simply call or e-mail the nearest authorized SimSci-Esscor technical support center. Full documentation is also available from these SimSci-Esscor centers. In addition to the easy-to-use keyword version of PIPEPHASE, SimSci-Esscor offers a version with a convenient Windows graphical user interface.

Typical Applications of PIPEPHASE

Both new design and the analysis of existing system applications are possible with PIPEPHASE. For new systems, PIPEPHASE can be used to size the various pipes and tubing, to determine required pump/compressor power and heater cooler duty, and to predict pressure, temperature, liquid holdup, velocity, flowrate, and flow pattern distributions throughout the system.

Field Production

Gathering Systems – Gathering systems, from the reservoir to the separation facilities or transmission pipeline, may be analyzed using PIPEPHASE. For wells, you may model inflow performance, completions, tubing/annuli flow, chokes, submersible pumps and gaslift. For the flowlines and trunklines, you may model pipes, chokes, separators, pumps, compressors, heaters, and coolers. The interaction between the surface lines and the well strings are modeled with the appropriate network mass and pressure equations. Each line of the network, both surface and downhole, are sub-jected to the heat balance relationships so that flowing temperatures can be pre-dicted. New gathering systems can be designed for optimum efficiency and old systems can be revamped.The effects of changing separator conditions or flowline size, for example, can easily be studied using case study analysis.

Gaslift Analysis – PIPEPHASE has four gaslift options. You may analyze the perfor-mance of wells which are currently on gaslift, maximize oil recovery using new gaslift, and determine which gaslift valves should be activated for a specified pro-duction scheme. This allows you to study each production well in a field over the life of the reservoir. You may determine which wells are candidates for gaslift, how pro-duction can be improved with gaslift, and which gaslift rates and valve locations are

2-4 Overview

required. For all gaslift options, the production fluid is considered to be in the tubing and the lift gas in the annulus around it.

Once the location of the gaslift valve and the amount of injection gas is determined, the performance of an entire gathering system can be analyzed in the Network mode.

Enhanced Oil Recovery – PIPEPHASE is not a reservoir model. However, it can be used to analyze water, steam, gas, nitrogen, and CO2 injection wells, complete with the outflow reservoir performance as predicted by a reservoir simulator, or as mea-sured by well-test data. PIPEPHASE can be used to predict injection rates and con-ditions, flowing bottomhole pressures, and similar phenomena. Of course, PIPEPHASE can also be used to analyze the transmission pipelines or distribution networks that deliver the injection fluids.

Re-Routing and Mothballing – For complex gathering and distribution networks, you may want to re-route part of the production and shutdown certain wells or entire gathering centers. This can be modeled with PIPEPHASE without coding new input files. New pipe links are manually inserted. Some engineering judgment should be exercised in selecting the scenarios as to how links are to be shut-in and new links added through the case study or time stepping utilities.

Transmission Pipelines

PIPEPHASE can simulate or predict the pressure and temperature profiles for an existing pipeline system that consists of various sizes of pipes, pumps, separators and other equipment. It accomplishes this using one or more of its industry standard pressure-drop correlations and its heat balance mechanism. Once the pressure and temperature profiles are calculated, they can be compared with measured data. In this manner, you can isolate problem areas and can investigate various remedies by further simulation.

Power and Duty Requirements – In addition to the pipe sizing for a new pipeline sys-tem, the horsepower of pumps and compressors and the duty of coolers and heaters must be determined. You can use PIPEPHASE to calculate these requirements based on either simulated or input suction and discharge conditions.

Insulation Requirement – For many pipelines, a balance must be reached between the retention and addition of heat. Heavy crudes usually have such high viscosities and sensitive temperature-viscosity functions that it is important to keep the flowing temperature as high as possible. Waterflood lines in cold environments must be kept above the freezing point. Liquid dropout and hydrate formation in gas and gas/con-densate lines can be limited by maintaining or increasing the flowing temperature. There are two ways of doing this - insulate the line or install heaters along the line. For onshore pipelines, burying the line or covering it with earth is sometimes an effective means of retarding heat loss. Generally, some combination of heaters, insu-lation, and burial constitutes an optimum or nearly optimum operation. Arctic envi-


ronments usually disallow the burial option because of damage to the permafrost layer.

PIPEPHASE allows prediction of heat loss through the pipe walls and of the perfor-mance of heaters installed at various locations along the pipeline. PIPEPHASE can also predict the formation of hydrates.

Cost calculations can be incorporated through the calculator unit operation.

Slug Catcher Sizing – The sphering, or pigging, calculation in PIPEPHASE predicts the quantity of liquids formed as a multiphase fluid flows in a pipeline and deter-mines the size of the liquid slug that is pushed out by the pig. The volume of a slug catcher tank must be at least as large as this liquid slug.

If only natural slugging occurs, good engineering practice dictates that the slug catcher vessel should be sized even larger than the calculated slug volume to account for transient pigging conditions and statistical uncertainty inherent in all liquid holdup predictions. Turndown simulation, i.e., holdup predicted for lower rates than the actual operating rate, should also be a part of any slug-catcher study.

LNG, Carbon Dioxide and Other Fluids – Because of its large library of component data and its variety of thermodynamic options, PIPEPHASE is not restricted to the traditional hydrocarbon fluids. This means that line sizing, capacity determinations, power and duty requirements, insulation calculations and station spacing can be investigated for LNG, dense-phase CO2 and similar fluids using PIPEPHASE.

Slug Catcher Sizing

The sphering, or pigging, calculation in PIPEPHASE predicts the quantity of liquids formed as a multiphase fluid flows in a pipeline and determines the size of the liquid slug that is pushed out by the pig. The volume of a slug catcher tank must be at least as large as this liquid slug.

If only natural slugging occurs, good engineering practice dictates that the slug catcher vessel should be sized even larger than the calculated slug volume to account for transient pigging conditions and statistical uncertainty inherent in all liquid holdup predictions. Turndown simulation, i.e., holdup predicted for lower rates than the actual operating rate, should also be a part of any slug-catcher study.

Solving Networks with PIPEPHASE

PIPEPHASE is an easy program to use, yet it incorporates sophisticated algorithms for calculating pressure drops and heat transfer in pipe networks. This section outlines the PIPEPHASE approach to solving piping.

2-6 Overview

Links

A link is a number of connected flow devices, fittings and equipment items arranged in series with only one inlet and one outlet. As shown in the figure below, a link comprises all pipes, fittings and equipment items from the fluid inlet to the outlet.

Figure 2-2: Example of a PIPEPHASE Link

Networks

A network is a number of links joined together at junctions. A network may have one or more inlets (sources), one or more outlets (sinks), loops, and crossovers. The following figure shows a typical network.

Figure 2-3: A typical PIPEPHASE Network

All networks are treated the same regardless of the number of sources, sinks, loops, and crossovers.


The Building Blocks

A network is divided into a number of links and each link is in turn divided into flow devices, fittings and process equipment items (pumps, valves, etc.). To carry out the pressure drop and heat transfer calculations, each flow device may be further subdivided into calculation segments. By default, each flow device is a single calculation segment.

Note: PIPEPHASE is a steady-state program; therefore, there must be an energy balance within each pipe segment.

The segment calculation takes into account frictional, elevational, and accelerational pressure drop components. Frictional pressure drop is due to the shear stress between pipe wall and fluid. Elevational pressure drop is a result of the conversion of fluid potential energy into hydrostatic pressure and the accelerational pressure drop is the gain or loss in pressure due to changes in velocity of the fluid. The following figure illustrates an PIPEPHASE calculation segment.

Figure 2-4: Calculation Segment

In addition to the pressure balance for the pipe segment, a heat balance is also performed. There must be a balance between heat coming into the segment and heat leaving it. Heat can enter or leave with the fluid or through the flow device walls. The transfer through the walls is governed by the temperature difference between the average fluid flowing temperature and the ambient temperature and by the overall heat transfer coefficient.

Joining Segments Together

The calculation segment pressure drop and temperature change equations are the heart of the PIPEPHASE calculations. For flow devices, the calculation segments are strung together and the solution procedure is sequential. Calculation begins at the inlet where the conditions are known. The heat and momentum balance equations are solved, in an iterative fashion for this first segment and the conditions at the other end are found.

2-8 Overview

These calculated conditions become the known conditions for the inlet to the next segment. Calculations progress sequentially until the end of the device is reached. Further flow devices are calculated in the same way until the end of the link is reached.

If an item of process equipment, such as a pump, is in the link, the calculated conditions for the outlet of the flow device become the known inlet conditions for this item. Then the equipment characteristic equations are solved.

Joining Links Together

A number of links may be joined together to form a network. A junction is the name given to the point where two or more links are joined. Since the fluid coming from all sources must equal the fluid leaving from all sinks, the net flow at each junction is zero. The coupled junction balance equations form a set of non-linear equations which must be solved numerically.

The primary method for solving these equations in PIPEPHASE is called the Pressure Balance Solution method.

Pressure Balance Solution Method

The Pressure Balance Solution Method (PBAL) is a Newton-Raphson method of solving pipeline networks. Derivatives for this method are calculated numerically.

Pressures at a junction or sink are calculated for each inflowing link. The pressure traverse in each link is calculated in the direction of flow from the inlet of the link to the outlet.

Convergence

For a junction or sink with multiple inflowing links and where you have not fixed the pressure:

• Pressures at a node (i.e., a sink, source, or junction) are calculated for each link inci-dent on the node. If the pressures are equal within a user defined tolerance, the node pressure (by pressure balance) has converged.

For fixed sink and junction pressures:

• Pressures at a node are calculated for each link incident on the node. When the cal-culated node pressure is equal to the set node pressure within the user defined toler-ance, the node pressure has converged.

If the pressure discrepancy is not within tolerance in any of the nodes, the Newton-Raphson method calculates new mass balanced link flowrate estimates and new source pressure estimates for the next iteration.


2-10 Overview

Chapter 3 Using PIPEPHASE

Chapter Contents

About This Chapter . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3Defining the Application . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3

Properties of Fluid Types . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3Flows and Conditions of Fluids . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4Sphering . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4Piping Structure . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4What PIPEPHASE Calculates . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4Rating, Design, Case Studies and Nodal Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5

Global Settings. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5Units of Measurement. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5Printout Options . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6Defaults . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7

Defining Fluid Properties. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8Defining Properties for Compositional Fluids . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8

Water as a Special Component . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9Library Components . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9Non-library Components . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10Petroleum Pseudocomponents . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10Assay Curve . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11Additional Component Capabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11Thermodynamic Properties and Phase Separation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12Transport properties . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13Tabular Data for Compositional Fluids . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14Multiple Thermodynamic Methods . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15Additional Thermodynamic Capabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15

Defining Properties for Non-Compositional Fluids. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 16Liquid . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 17Gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 17Steam . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 18Gas Condensate. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 18


Blackoil. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19Defining Properties for Mixed Compositional/Non-Compositional Fluids . . . . . . . . . . . . . . 20Generating and Using Tables of Properties . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 20Sources. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 21

Compositional Sources. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 21Non-Compositional Sources. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 21

Structure of Network Systems . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 22Controlling Convergence of Networks (PBAL). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 22Networks. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 23

PIPEPHASE Flow and Equipment Devices . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 24Flow Devices (have length) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 24Equipment Devices (have no length) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 25Fittings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 25Process Equipment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 25Unit Operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 26Flow Device Sizing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 26

Pressure Drop Calculations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 27Pressure Drop in Flow Devices . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 28Nominal Diameter and Pipe Schedule . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 30Pressure Drop in Completions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 31Pressure Drop in Fittings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 32

Equipment Items . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 34Heat Transfer Calculations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 37

Detailed Heat Transfer in Pipe and Tubing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 38Gaslift Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 39Sphering or Pigging . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 40Reservoirs and Inflow Performance Relationships . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 40Production Planning and Time-Stepping. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 41

Time Changes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 41Wells and Well Grouping. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 41Reservoir Depletion . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 42Facilities Planning . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 42

Subsurface Networks and Multiple Completion Modeling . . . . . . . . . . . . . . . . . . . . . . . . . . . 43A Single Well . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 43More Than One Well . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 44Multiple Completions. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 44

Case Studies. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 45Global Changes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 46Individual Changes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 46

Nodal Analysis. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 47Dividing the Link . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 47Selecting Parameters and Flowrates. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 47Sensitivity Results . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 47Grouping Parameters . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 48

3-2 Using PIPEPHASE

About This Chapter

This chapter contains information about the way PIPEPHASE works, the data that need to be supplied by the user, and the correlations used.

This chapter is arranged according to what you want to do, the type of fluid you have, and the type of pipeline network. For each of the capabilities of PIPEPHASE, this chapter explains which data you are required to provide the program, and which data you may optionally supply. Throughout this chapter, the right hand column contains page numbers in Chapter 4, Input Reference, and to a STATEMENT on that page where you will find details on how to format the data.

PIPEPHASE uses the industry-standard PRO/II physical property and thermodynamic package. In these cases, page references are to the SimSci Component and Thermodynamic Data Input Manual.

Defining the Application

The first thing you should do before using PIPEPHASE is to decide what type of application you have. This depends on:

• The properties of the fluid(s) flowing through the piping system,

• The flowrates and conditions at which those fluids enter and leave the piping system,

• The structure and elements of the piping system, and

• Other special processes you may want to simulate, such as Sphering.

Properties of Fluid Types

There are seven types of fluid modeled in PIPEPHASE:

• Compositional

• Compositional Blackoil

• Non-compositional

• Blackoil

• Gas Condensate

• Gas

• Liquid

• Steam


Compositional fluids are defined as mixtures of chemical components with a known composition. For compositional fluids, PIPEPHASE will calculate the phase split whenever prevailing process fluid conditions demand. However, you may instruct PIPEPHASE to assume the fluid is one phase at all times, thus reducing the time the program takes to solve by bypassing the vapor-liquid equilibrium (flash) calculation. Compositional blackoil allows selective compositional input for blackoil analysis and reporting.

Non-compositional gases and liquids are single-phase. Blackoil is a liquid-dominated, two-phase model. Gas Condensate is a gas-dominated, two-phase model. Steam is a single component, two-phase model.

Flows and Conditions of Fluids

Fluids enter piping systems at sources and leave at sinks. Fluids with different properties may enter at different sources, but they must all be of the same type.

In general, you have to assign flowrates, temperatures and pressures to sources and/or sinks. For compositional fluids, you also have to assign compositions to the source fluids. The exceptions are explained in What PIPEPHASE Calculates later in this chapter.

Sphering

Special applications, relevant to oil production, can be modeled with PIPEPHASE. Sphering or Pigging is used to increase gas flow efficiency in wet gas and gas dominated multiphase pipelines.

Piping Structure

Before beginning to input problem data into the application, is important that you convert the structure of the piping system into a simpler schematic representation of the relevant nodes (i.e., sources, junctions, and sinks) and links. Label each node and link both uniquely and logically for future reference.

What PIPEPHASE Calculates

PIPEPHASE solves the equations that define the relationship between pressure drop and flowrate. PIPEPHASE can also calculate heat losses and gains.

With a single link, PIPEPHASE will calculate the pressure drop for a known flowrate. Alternatively, for a given pressure drop, PIPEPHASE will calculate the flowrate.

With a network configuration, you must supply a known flowrate or pressure at each source and sink and PIPEPHASE will calculate the unknowns. The combination of knowns that you are allowed to supply are explained in this chapter.

3-4 Using PIPEPHASE

Rating, Design, Case Studies and Nodal Analysis

PIPEPHASE works in both rating and design modes. In rating mode, you supply data about the pipes, fittings and equipment and PIPEPHASE calculates the pressure and temperature profiles. In design mode, PIPEPHASE calculates line sizes. Case studies can be performed in either mode.

Nodal analysis is a powerful graphical technique commonly used by production engineers reviewing individual wells or pipelines. The graph clearly represents the performance characteristic envelope of the link. Nodal analyses can be performed only on a single link.

Global Settings

Before you provide PIPEPHASE with information about the fluid and piping structure of your problem, global parameters may be set and the problem definition described. Choices can be made on how to control the simulation, define the input units, specify how much output you want, and set global defaults for use throughout the simulation.

Units of Measurement

PIPEPHASE allows you to construct a group of units of measure (or dimensions) which are to be used throughout all the simulation input. However, you may locally override individual units of measure where necessary. The output will always be in the units supplied on the DIMENSION statement, unless specific output overrides or supplements

To provide... See...

Descriptive text

You must use a TITLE statement that denotes that the input has started. The only word that has to appear on this statement is TITLE.

p. 4-14 TITLE

On the TITLE statement you may supply text; this text will appear at the top of every page of output, and will make the run easier to identify.

p. 4-14 TITLE

You can further describe the problem using up to four lines of 60 characters each.

p. 4-14 DESCRIPTION

If you are using the Case Study facility, you may add one line of description for each case study. You will find further details about case studies later in this chapter.

p. 4-154 DESCRIPTION

If you are using the Sensitivity (nodal) Analysis facility, you may add two lines of description, one for inflow and one for outflow. You will find further details about nodal analysis later in this chapter.


Input data checking

You may use PIPEPHASE just to check your input syntax and topology and not to perform any calculations.

p. 4-20 CALCULATION


are requested on the OUTDIMENSION statement.

Printout Options

PIPEPHASE generates a great deal of data during its calculations. The default printout is normally sufficient for most engineering applications. You may increase or decrease the amount of output depending upon your requirements. For further details describing the output printout, see Chapter 5, Results.

To provide... See...

Input units Global units of measurement are defined at the beginning of the input. PIPEPHASE has four pre-selected sets for user convenience: Petroleum, English, Metric and SI. You should select the set that is closest to your requirements. You can then re-define units of measurement either globally at the start of the input or individually when you supply the data. If you do not select a set, PIPEPHASE defaults to the English set.

p. 4-14 DIMENSION

To set the... See...

Output units The default units of measurement for output are the same as those defined globally for input on the DIMENSION statement. Using the OUTDIMENSION statement, you may define a separate set of units for the output.

p. 4-31 OUTDIMENSION

Input reprint You will always get a reprint of your input keyword file. PIPEPHASE then reprints its interpretation of the input. You may suppress this interpretation output.

p. 4-28 PRINT

PVTGEN Tables and plots can be requested when generating property data.

p. 4-28 PRINT

Iterative results During solution of a network, PIPEPHASE iterates until it converges to within the set tolerance. You can request a printout that shows intermediate results. The results can provide clues which help to converge large or sensitive networks.

p. 4-28 PRINT

Flash results In a compositional run, PIPEPHASE prints out phase equilibrium details and the properties of the phases at each node. This output can be suppressed.

p. 4-28 PRINT

Devices You can request a range of detail for different devices. In addition, special outputs are produced for sphering.

p. 4-28 PRINT

Properties output

PIPEPHASE can output all properties used in the detailed calculations.

p. 4-28 PRINT

3-6 Using PIPEPHASE

Defaults

Many of the data items required by PIPEPHASE have default values assigned to them. If you do not explicitly specify a value for an item of data, or select a calculation method, the program will automatically assign a value or method. For example, pipe thermal conductivity assumes a default value of 29 BTU/hr-ft-oF if you do not specify a value. Similarly, the Moody method for single-phase pressure drop calculations is chosen, by default, as it is generally suitable for many engineering purposes. Beware, these default selections are not neccessarily the most appropriate, or best for your particular application. They do not substitute for engineering judgement. If an doubt, especially for the choice of a calculation method, consult chapter 4 of the manual for advice.

For convenience, PIPEPHASE allows you to change some defaults globally at the start of the input.

Plotting options In addition to tabular data, line printer plots of pressure and temperature versus distance may be requested. The Taitel-Dukler flow regime map may also be produced for links operating in two-phase flow. Phase Envelope and Nodal Analysis plots may also be generated.

p. 4-28 PRINT

Results Access System (RAS)

Using the Results Access Database, you may examine data that have been produced by a keyword run of the program. You may also print or plot the results using EXCEL.

p. 4-28 PRINT

To define... See...

Flow device parameters

You can specify global values for the pipe, tubing and annulus inside diameter, the surrounding medium, and the parameters associated with pressure drop and heat transfer. You can override these settings for individual pipes.

p. 4-24 DEFAULTp. 4-92 PIPEp. 4-95 TUBINGp. 4-94 ANNULUS

Heat transfer You can define the heat transfer for pipes, tubings, and annuli as an overall coefficient or by defining the parameters - viscosity, conductivity, velocity, etc. - for the surrounding soil, air, or water. You can select a medium and optionally override these settings for individual pipes. You can globally suppress heat transfer calculations and then reinstate them for individual pipes, tubings, and annuli.

p. 4-24 DEFAULTp. 4-92 PIPEp. 4-95 TUBINGp. 4-94 ANNULUS

Pressure drop methods

You can globally set the pressure drop method and the Palmer parameters for liquid holdup. You can override the pressure drop method for individual pipes, tubing, and annuli.

p. 4-21 FCODEp. 4-92 PIPEp. 4-95 TUBINGp. 4-94 ANNULUS

To set the... See...


Defining Fluid Properties

PIPEPHASE requires the properties of the fluid to calculate pressure drops, heat transfer, and phase separation. There are two major classifications of fluid models: compositional and non-compositional.

A fluid model is compositional when it can be defined in terms of its individual components either directly or via an assay curve. PIPEPHASE will then predict the fluids properties by applying the appropriate mixing rules to the pure component properties. Unless PIPEPHASE is instructed otherwise, it will perform phase equilibrium calculations for the fluid and determine the quantity and properties of the liquid and vapor phases.

A fluid model is non-compositional when it can be defined with correlations based on measurable properties.

Defining Properties for Compositional Fluids

PIPEPHASE requires thermodynamic and transport properties to calculate phase splits, pressure drops, and heat transfer.

All required properties of compositional fluids are predicted from the properties of the pure components. These are mixed to get the stream properties of the fluid.

There are three methods for defining a component:

1. Selecting individual components from the SimSci library,

2. Defining individual components as petroleum pseudocomponents,

3. Defining an assay curve and having the thermodynamic model divide it into petro-leum cuts.

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

Transitional flow You can globally set the transitional Reynolds Number between laminar and turbulent flow regimes.

p. 4-21 FCODE

Limits You can change the maximum and minimum values of temperature and pressure for flash calculations. If the program detects conditions outside these limits, warning messages will be presented in the output.

p. 4-28 LIMITS

To define... See...

3-8 Using PIPEPHASE

Water as a Special Component

PIPEPHASE can rigorously predict phase separations involving more than one liquid phase. However, there is a simplified way of dealing with water in hydrocarbon systems. Because water is only sparingly soluble in oil, a hydrocarbon system with a significant amount of water will often form two liquid phases. PIPEPHASE will handle calculations involving water in hydrocarbons by one of two methods:

1. It can calculate the solubility of water in the hydrocarbon phase and put the excess water into a pure aqueous phase. All the aqueous phase properties will be calculated separately from those of the hydrocarbon phase.

2. It can perform a rigorous three phase flash to determine the composition of each phase.

Library Components

The SimSci library contains over 1700 components. A full list is available in the SimSci Component and Thermodynamic Data Input Manual. For all components, the databank contains data for all the fixed properties and temperature-dependent properties necessary to carry out phase equilibrium calculations. For all common components, the databank also contains a full set of transport properties necessary to carry out pressure drop and heat transfer calculations. If you need to supplement the data, or override the library data with your own, you may do so.

To specify... See...

Library components

All fixed property data may be accessed from the SimSci databank. All you need to do is supply the name of the component.

p. 4-33 COMPONENT

Library components

You may override the SimSci constant properties for any or all of the components.

p. 4-37 MWp. 4-37 SPGRp. 4-37 APIp. 4-37 ACENTRICp. 4-37 ZCp. 4-37 TC()p. 4-37 PC()p. 4-37 NBP()p. 4-37 STDDENSITY()p. 4-38 VC

You may override the SimSci variable (temperature-dependent) properties for any or all of the components.

p. 4-38 VP()p. 4-38 ENTHALPY()p. 4-38 CP()p. 4-38 LATENT()p. 4-38 DENSITY()p. 4-38 VISCOSITY()p. 4-38 CONDUCTIVITY()p. 4-38 SURFACE()


Non-library Components

You may use components not found in the SimSci library. You must input all the necessary data for thermodynamic and transport properties.

Petroleum Pseudocomponents

To define hydrocarbon pseudocomponents, you must supply at least two of the following three parameters:

1. Molecular weight

2. Gravity

3. Normal boiling point

PIPEPHASE will predict the third if you omit it. PIPEPHASE uses industry-standard characterization methods to predict all fixed and temperature-dependent property data for each pseudocomponent. You may select the method most suitable for your own mixture.


Non-library components

If you want to use a component that is not in the SimSci Bank, you must supply its name and all the required properties.

SimSci Component and Thermodynamic Data Input Manual

To define... See...

Pseudo- components

Define petroleum pseudocomponents by supplying at least two of the following: molecular weight, gravity, and normal boiling point.

p. 4-34 PETROLEUM

Property- calculation methods

You may select the method PIPEPHASE will use to calculate the properties of your pseudo-components.

p. 4-35 ASSAY

Fixed Property Data

You can supply your own fixed property data to override the data that PIPEPHASE uses from its own internal library.

p. 4-37 MWp. 4-37 SPGRp. 4-37 APIp. 4-37 ACENTRICp. 4-37 ZCp. 4-37 TC()p. 4-37 PC()p. 4-37 NBP()p. 4-37 STDDENSITY()p. 4-38 VC

3-10 Using PIPEPHASE

Assay Curve

If your fluid is defined by an assay curve (TBP, D86, D2887, or D1160), PIPEPHASE will divide it into a number of cuts. You can control the number of cuts and the ranges they cover. Each of the cuts is then treated as a pseudocomponent, as described previously. You may also define a lightends analysis to go with the assay curve.

Additional Component Capabilities

All the features of SimSci-Esscor’s industry-standard component property databank and methods have been incorporated into PIPEPHASE. These are summarized below in Table 3-1. For details of these methods and their applicability, please consult the SimSci Component and Thermodynamic Data Input Manual, in the volume detailed below.

Variable Property Data

You can supply your own temperature-dependent property data to override the data that PIPEPHASE predicts.

p. 4-38 VP()p. 4-38 ENTHALPY()p. 4-38 CP()p. 4-38 LATENT()p. 4-38 DENSITY()p. 4-38 VISCOSITY()p. 4-38 CONDUCTIVITY()p. 4-38 SURFACE()

To supply... See...

Assay Data You supply an assay curve, and PIPEPHASE will divide it into petroleum cuts. You supply it in the form of D86, D1160, D2887, TBP, or TBP at 10 mm Hg curves.

Page 4-35 D86, D1160, D2887, TBP, TBP10

You must also supply gravity as API or specific gravity or UOP K-factor either as a curve against percent vaporized or as an average value.

Page 4-37 API, SPGR, UOP, DATA

PIPEPHASE will calculate molecular weight data, or you may supply it as an average or a curve against percent vaporized.

Page 4-37 MW

You may define the number of petroleum fractions to be generated and their temperature ranges.

Page 4-36 CUTPOINTS

You may select the method PIPEPHASE will use to calculate the properties of the generated petroleum fractions.

Page 4-35 ASSAY

Mixed component types

You can mix defined components and pseudocomponents with assay data by defining a lightends composition and rate for each source.

Page 4-83 LIGHTENDS

To define... See...


Table 3-1: Summary of Other Component Property Options

Thermodynamic Properties and Phase Separation

PIPEPHASE can use a generalized correlation, an equation of state, or a liquid activity method to calculate thermodynamic properties at the flowing conditions and hence to predict the split between the liquid and vapor phases. The choice of the thermodynamic property calculation method depends on the components in the fluid and the prevailing temperatures and pressures. PIPEPHASE also provides a number of methods that can rigorously calculate vapor-liquid-liquid equilibrium and solid-liquid equilibrium. Recommendations for the commonly found pipeline systems are provided below.

Table 3-2: Recommended Methods for Thermodynamic Properties

You can specify methods that you want to use for the following thermodynamic

Option Summary Chapter

Synthetic components

You may characterize a component as a synfuel of a specific type or as a mixture of different petroleum types.

Volume 1

Other fixed property requirements

Rackett parameter is required for the Rackett method for liquid densities. Dipole moment and Radius of gyration are required for the Hayden-OConnell method for vapor properties. Hildebrand solubility parameter and liquid molar volume are required for various generalized and liquid activity thermodynamic correlations.Van der Waal’s area and volume are required for UNIFAC and UNIQUAC liquid activity thermodynamic correlations.

Volume 1

Properties from structure

You may define the structure of non-library components for use with the UNIFAC thermodynamic method.

Volume 1

Method

Property Heavy Hydrocarbon Systems

Light Hydrocarbon Systems

Natural Gas Systems

K-value Braun K10 (<100 psia)Grayson-StreedPeng-RobinsonSoave-Redlich-Kwong

Peng-RobinsonSoave-Redlich-KwongLee-Kesler-PlckerBenedict-Webb-Rubin-StarlingChao-Seader

Peng-RobinsonSoave-Redlich-Kwong

Enthalpy Curl-PitzerJohnson-GraysonLee-KeslerPeng-RobinsonSoave-Redlich-Kwong

Peng-RobinsonSoave-Redlich-KwongLee-Kesler-PlckerBWRSCurl-PitzerLee- Kesler


Liquid density APILee-Kesler

APILee-Kesler

APILee-Kesler

Vapor density Peng-RobinsonSoave-Redlich-Kwong




properties.

Transport properties

The SimSci databank contains pure component data for the thermal conductivity, surface tension, and viscosity of liquids and vapors as functions of temperature. You can choose to use these data and simple mixing rules to predict the flowing properties of the fluid.

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


K-values, enthalpy, density

You must select a thermodynamic method for calculating the vapor-liquid equilibrium and mixture properties from component properties. Either select a system with a predefined method for each property, or select an individual method for each property.

p. 4-48 METHOD

Vapor-liquid-liquid equilibria

Use the (VLLE) qualifier on the SYSTEM keyword or on the KVALUE keyword or have a second KVALUE keyword with an (LLE) qualifier.

p. 4-48 METHOD

Different enthalpy methods for liquid and vapor

You must include two ENTHALPY keywords, one with an (L) qualifier and one with a (V) qualifier.

p. 4-48 METHOD

Different density methods for liquid and vapor

You must include two DENSITY keywords, one with an (L) qualifier and one with a (V) qualifier.

p. 4-48 METHOD

Aqueous phase enthalpy

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

p. 4-52 WATER

Binary interaction parameters

For some systems, notably close-boiling mixtures, the standard equations do not adequately reproduce experimental phase equilibria data. You may improve the predictability of many of the equations of state, or liquid activity coefficient methods by inputting your own binary interaction parameter values. For example, you can tune the PR, SRK, BWRS and LKP equations.

p. 4-53 PRp. 4-53 BWRS


About 60 of the bank components have data for viscosity and thermal conductivity from the GPA TRAPP program. If you choose to use the TRAPP data, all of your components must be TRAPP components and you cannot have any pseudocomponents or assay data. For a listing of TRAPP component names, see the SimSci Component and Thermodynamic Data Input Manual.

Tabular Data for Compositional Fluids

For large scale compositional simulations, a table of fluid properties can be specified at the start of the run. This will reduce the computation time by eliminating flash calculations during the solution procedure. This method is applicable if all the sources in the network have the same composition, and the compositions are constant throughout the network.


Prediction methods

You may choose a method for calculating bulk transport properties from component properties. Select a system with predefined methods for each property, or select an individual method for each property.

p. 4-48 METHOD

Overriding viscosity

To override the mixture liquid viscosity predictions, you may supply a liquid viscosity curve for either the hydrocarbon liquid phase, the water phase or the total liquid. A different viscosity curve may be supplied for each source.

p. 4-54 SET

To... See...

Build and use a table

You can have PIPEPHASE build the table and use it in the same run.

p. 4-64 DIMENSION

Retrieve a table Alternatively, you can have PIPEPHASE build the table, store it in a file, and then use it in a subsequent run. PIPEPHASE will not build a table for use in the same run while also storing it for a subsequent run.

p. 4-20 CALCULATIONp. 4-64 DIMENSIONp. 4-70 FILE


Multiple Thermodynamic Methods

In most cases, a single set of thermodynamic and transport methods is adequate for calculating properties of all sources. However, your flowsheet may contain sources with widely varying compositions or conditions such that they cannot be simulated accurately using just one set. To account for this, you may define more than one set of methods (there is no limit) and apply different sets to different sources.

Additional Thermodynamic Capabilities

All of SimSci’s industry-standard thermophysical property calculation methods have been incorporated into PIPEPHASE. These are summarized in the following table. For details of these methods and their applicability, please consult Chapter 2 in the SimSci Component and Thermodynamic Data Input Manual.


More than one thermodynamic set

For each set use a separate METHOD statement. Name the set using the SET keyword.

p. 4-48 METHOD

The set used by a source

Link the source to the thermodynamic set using the SET keyword.

p. 4-75 SOURCE

A default thermodynamic set

When a single set is present, all sources use that set. If you do not link the source to a thermodynamic set, it will use the default set. Normally this is the first set that appears in the input. If you want to stipulate that another set is the default, use the DEFAULT keyword.The thermodynamic set can also be set for junctions with streams feeding the junctions and being mixed using the new method.

p. 4-48 METHOD


Table 3-3: Summary of Other Thermodynamic Options

Defining Properties for Non-Compositional Fluids

A non-compositional fluid model must be defined as blackoil, gas condensate, liquid, gas, or steam. Blackoil and gas condensate are two-phase, with one phase dominant. Gas and liquid fluid models are single-phase. Steam may be single or two-phase.

Option Methods

Generalized Correlations

Grayson-StreedImproved-Grayson-StreedGrayson-Streed-ErbarBraun-K10

Chao-SeaderChao-Seader-ErbarIdeal

Equations of State Soave-Redlich-KwongSRK-Kabadi-DannerSRK-Huron-VidalSRK-Panagiotopoulos-ReidSRK-ModifiedSRK-SimSciSRK-Hexamer

Panagiotopoulos-ReidPeng-RobinsonPR-Huron-VidalPR-Panagiotopoulos-ReidBWRSUniwaals

Liquid Activity Methods

Non-random Two-liquid EquationUniversal Quasi-chemical (UNIQUAC)van LaarWilsonMargulesRegular Solution TheoryFlory-Huggins Theory

Universal Functional Activity Coefficient (UNIFAC)Lyngby-modified UNIFACDortmund-modified UNIFACModified UNIFAC methodFree volume modification to UNIFACIdeal

Special Packages GlycolSour waterGPA Sour Water

AmineAlcohol

Other Features Heat of mixingPoynting correction

Henry’s LawAmine Residence Time Correction


Fluid definition You must tell PIPEPHASE the type of fluid you have: blackoil, gas condensate, liquid, gas, or steam.

p. 4-20 CALCULATION

Different data for different sources

You may supply specific gravities for each source.

p. 4-54 SET


Liquid

All properties of a non-compositional liquid are calculated by PIPEPHASE from the specific gravity and built-in correlations.You may choose from the viscosity correlations shown in Table 4-25, Property Correlations.

Gas

All properties of a non-compositional gas are calculated by PIPEPHASE from the specific gravity and the built-in correlations. You may choose which viscosity correlation to use from the list in Table 4-25, Property Correlations.


Liquid definition You must define the liquid as water or hydrocarbon, and supply its gravity. If the liquid is water, the specific gravity must be 1.0 or greater.

p. 4-54 SET

Viscosity method You may define the method that PIPEPHASE uses to predict non-compositional liquid viscosity.

p. 4-57 SET for Blackoil

Overriding viscosity data

You may supply liquid viscosity data to override the internally predicted data. You may define the viscosity as a single value or as a two-point viscosity curve.

p. 4-54 SET

Specific heat You may supply a single constant value for liquid specific heat to override the internally predicted data.

p. 4-54 SET


Gas definition A non-compositional gas is defined in terms of its gravity, and PIPEPHASE will use the appropriate correlations to predict its properties.

p. 4-54 SET

Viscosity method You may define the method that PIPEPHASE uses to predict non-compositional gas viscosity.


Cp/Cv ratio definition

A gas specific heat ratio may be defined to override the internal value used as default.

p. 4-54 SET

Define a contaminant

One or more of the following gas contaminants may also be defined: nitrogen, carbon dioxide, or hydrogen sulfide.

p. 4-54 SET

Gas Z-factor The method that PIPEPHASE uses to predict a non-compositional compressibility factor may also be defined.



Steam

Steam is a non-compositional fluid that is allowed to exist in two phases. You cannot override the steam table data contained within PIPEPHASE’s data libraries. However, all pressure drop correlations which are available to compositional fluids are also available to the steam model.

Gas Condensate

Gas condensate is a multiphase non-compositional fluid with gas predominating. All properties of gas condensate are calculated by PIPEPHASE from the phase specific gravities, condensate gas ratio at standard conditions, and built-in correlations.


Steam tables If the fluid is steam, use the program’s internal steam tables. You may specify that the gravity of the condensed water is more than 1.0 to take into account dissolved solids.

p. 4-55 SET for Steam

Saturated steam You may specify steam quality if the steam is saturated. Specify the temperature and quality if the steam is superheated or the water is subcooled.

p. 4-75 SOURCE


Condensate definition

A gas condensate is defined in terms of its gravity, condensate gas ratio, and PIPEPHASE will use the appropriate correlations to predict its properties.

p. 4-56 SET for Condensate

Specific gravity You must supply specific gravity data for gas, liquid and water phases, even if you do not expect them all to be present.


Contaminants One or more of the following gas contaminants may also be defined: nitrogen, carbon dioxide, or hydrogen sulfide.



Blackoil

Blackoil is a multiphase fluid model which predicts properties from the gas gravity, oil gravity, and the volume of gas per unit volume of liquid.


Blackoil definition Blackoil is defined in terms of the gravity of its oil and gas and the Gas to Oil ratio. PIPEPHASE will use the appropriate correlations to predict its properties.


Specific gravity You must supply specific gravity data for gas, liquid, and water phases, even if you do not expect them all to be present.


Viscosity You may optionally enter liquid viscosity data in the form of a Tabular viscosity curve.


Contaminants One or more of the following gas contaminants may also be defined: nitrogen, carbon dioxide, or hydrogen sulfide.


Adjustment of Properties

You may adjust the properties that PIPEPHASE calculates from its built-in correlations so that they more closely fit measured laboratory data.

p. 4-58 ADJUST (Blackoil only)

Lift gas definition When you have a GLVALVE in the simulation, you need to define the lift gas in terms of Gravity and (optionally) contaminants.

p. 4-59 LIFTGAS (Blackoil only)

Tabular data If laboratory data are available, you may input them and override the PIPEPHASE internally generated data. If you use tabular data, you must input all data: Formation Volume Factor, Solution Gas Oil Ratio, Live Viscosity, and Gravity.

p. 4-59 TABULAR (Blackoil only)p. 4-60 FVF (Blackoil only)p. 4-61 SGOR() (Blackoil only)p. 4-61 VISCOSITY() (Blackoil only)p. 4-61 GRAVITY() (Blackoil only)

Gas Z-factor The method that PIPEPHASE uses to predict a non-compositional compressibility factor may be defined.

p. 4-62 CORRELATION

Viscosity method You may define the method that PIPEPHASE uses to predict viscosities and blending rules.

p. 4-62 CORRELATION


Defining Properties for Mixed Compositional/Non-Compositional Fluids

PIPEPHASE offers the user the ability to define blackoil models that combine data from:

• Sources that are in the standard blackoil format (see description of blackoil inputs),

with

• Sources that are in the standard compositional format (see description of composi-tional inputs).

PIPEPHASE treats the combined fluid model as a blackoil model; flash calculations are used to define the appropriate blackoil properties for the compositional sources. The inputs to the compositional blackoil model are thus a combination of the inputs to separate compositional and blackoil models.

Generating and Using Tables of Properties

For large scale compositional or blackoil simulations, a table of fluid properties can be built and used. This will reduce the computation time by phase separation calculations during the solution procedure. This method is applicable if all the sources in the network have the same composition or Blackoil properties.

Formation volume factor and solution gas oil ratio methods

You may define the methods that PIPEPHASE uses to calculate formation volume factor and solution gas oil ratio.

p. 4-62 CORRELATION

To... See...

Build and use a table

You can have PIPEPHASE build the table and use it in the same run.

p. 4-66 GENERATE (for Blackoil)

Retrieve a table Alternatively, you can have PIPEPHASE build the table, store it in a file, and then use it in a subsequent run. PIPEPHASE will not build a table for use in the same run while also storing it for a subsequent run.

p. 4-20 CALCULATIONp. 4-66 GENERATE (for Blackoil)p. 4-70 FILE



Sources

A source is a point at which fluid enters the piping system. You define a source by supplying parameters such as composition, temperature, pressure, and flowrate. You can have more than one source in a network.

Compositional Sources

Non-Compositional Sources


Defined components

You must define the total flowrate and composition of the source stream. Components can be either from the PIPEPHASE component library or defined as pseudocomponents.

p. 4-75 SOURCE

Assay data A source fluid may be defined by an assay curve. You can combine library components and/or petroleum pseudocomponents with an assay curve by supplying a lightend analysis.

p. 4-75 SOURCEp. 4-83 LIGHTENDS

Viscosity data To override the internally generated fluid viscosity data, you may specify a viscosity curve in the PVT data section.

p. 4-54 PVT

Similar sources To reduce redundant data entry, you may refer to a predefined source. Parameters may be specified to override the parameters that are different.

p. 4-75 SOURCE


Steam sources You must define the pressure and quality of a saturated steam source. The temperature must be specified only if the steam is superheated (Quality=100%) or subcooled (Quality=0%).

p. 4-75 SOURCE

Gas, liquid, blackoil or condensate sources

One or more sets of fluid property data are defined in the PVT data section. You must assign a unique set number to each data set. Each source must be referred to the appropriate data set number.

p. 4-75 SOURCEp. 4-54 PVT

Well In-flow Performance

You may specify the IPR of a well source for a single link with gas, liquid, blackoil or condensate. You may enter values for the Vogel and Productivity Index parameters. You may also supply well test data.Well test data

p. 4-75 SOURCEp. 4-80 WTEST

Similar sources If one source is the same as or similar to another, you may refer it to the other source. PIPEPHASE will copy all the data from one source to the other. You may then override the parameters that are different.

p. 4-75 SOURCE


Structure of Network Systems

Flow devices such as pipes, fittings, and other process equipment are connected together in a Link. Each Link starts at a Node (a Source or a Junction) and ends at another Node (a Junction or a Sink).

PIPEPHASE can calculate either simple or complex network problems. A simple network problem, e.g. a single link, is defined as a series of pipes, fittings, and process equipment that has one source, one sink, and no junctions. A more complex network may have one or more sources and one or more sinks. See Chapter 2, Overview, for terminology and examples of single links and networks.

PIPEPHASE calculates the flowrates and pressure drops. In a network configuration, you must either define these parameters or provide an estimate at each node.

Controlling Convergence of Networks (PBAL)

A system of non-linear equations based on Kirchoff’s laws represents the network problem. A Newton like technique is applied iteratively, until the solution converges to a specified tolerance. If the solution diverges (in sensitive networks), user specified damping factors and constraints may be set to stabilize the convergence path.


Network solution algorithm

There are two solution algorithms available for Networks. For the vast majority of networks, you would use the default PBAL method. If your fluid is a single-phase liquid or gas, you may find that the MBAL method gives a faster solution.

p. 4-40 SOLUTION


Automatic generation of initial estimates

PBAL has a choice of methods. By default, PBAL generates flowrate estimates by considering the diameters of the first pipe in each link. An alternative method uses the frictional resistances of the pipes in each link. A third method solves the first iteration with MBAL before going into PBAL. Finally, if you have solved this network before and just changed some of the conditions, you may instruct the program to use your previous solution as its initial estimate.

p. 4-40 SOLUTION

User-supplied initial estimates

You may also provide individual estimates for junction pressures and link flowrates.

p. 4-88 JUNCTIONp. 4-89 LINK

Maximum and minimum flows

For any link, you may specify the maximum and minimum flows that are to be allowed.

p. 4-89 LINK


Networks

A network generally has more than one link and one or more junctions. The variables are the pressure and flowrate at each source and sink. You specify the values of the variables that are known, and PIPEPHASE will calculate the unknowns. In order not to under- or over-specify the system, simple rules must be followed in constructing the problem:

• You must specify a number of knowns equal to the total number of sources and sinks.

Controlling convergence

In some difficult networks, convergence of the base case can be improved by adjusting various convergence parameters: for example, damping, relaxation, internal tolerances, etc. Refer to Chapter 6, Technical Reference, for details.

p. 4-40 SOLUTION

Direction of flow If you know the flow direction in all links, you can specify that PIPEPHASE not try to reverse them from iteration to iteration.

p. 4-40 SOLUTION

Solution tolerance The network calculation converges when the error is within a given tolerance. You may optionally change this tolerance.

p. 4-44 TOLERANCE

Calculation time If PIPEPHASE does not converge within a certain number of iterations, it will stop and report the results of the last iteration. You may reduce or increase the maximum number of iterations. To reduce calculation time in large compositional runs, you may control the number of fluid property evaluations that are performed in each link for the PBAL initialization procedure.

p. 4-40 SOLUTION

Closed loops If the flows inadvertently form closed flow paths at any iteration, PIPEPHASE will repair these and optionally take remedial action.

p. 4-40 SOLUTION

Pipe segments Pipes, tubing, and annuli are divided into segments for pressure drop and heat transfer calculations. You can change either the number of segments or the length of segments for greater calculational accuracy.

p. 4-26 SEGMENT

Check valves You may allow regulators (unidirectional check valves) to pass a small backward flow.

p. 4-40 SOLUTION

Critical flow in chokes

Critical flow in chokes can cause difficulties for convergence algorithms. To help PIPEPHASE solve such networks, you can choose from three options.

p. 4-40 SOLUTION

Wells You can prevent well flows from falling below the minimum required to transport fluid in a two-phase system.

p. 4-40 SOLUTION



• You must specify at least one pressure.

• If any source or sink flowrate is an unknown, you must supply an estimate.

• If you do not know a pressure at a source, sink, or junction, you do not need to sup-ply an estimate. You may specify estimates to speed up convergence.

PIPEPHASE Flow and Equipment Devices

A piping system is made up of links which join sources, sinks, and junctions. Each link consists of a series of flow devices: pipes, fittings, and process equipment and unit operations.

Sources and sinks must be named. The location and the direction of flow of each link are implied by the FROM and TO keywords on the LINK statement.

The statements describing the devices in the link must follow the LINK statement and be in the order in which the devices appear in the link.

Flow Devices (have length)

Descriptions of the flow devices available in PIPEPHASE are as follows:


Sources and sinks

You must have at least one source and at least one sink.

p. 4-75 SOURCEp. 4-87 SINK

Junctions You must have a junction at the point where two or more links meet. If your network is complex, you may help the convergence by supplying estimates for the junction pressures.

p. 4-88 JUNCTION

Links You must supply a unique name for each link. If your network is complex, you may speed up the solution by supplying estimates for flowrates through each link.

p. 4-89 LINK

Steam networks PIPEPHASE can model preferential splitting at Tee junctions in pure distribution networks. These junctions can have only two outgoing and one incoming link.

p. 4-88 JUNCTION

Subnetworks PIPEPHASE has a number of devices that invoke a special algorithm. You may specify the inlet conditions; PIPEPHASE breaks the flowsheet at the inlet and solves the resulting subnetworks simultaneously so that the pressures match.

p. 4-103 MCOMPRESSp. 4-127 MCHOKEp. 4-128 MREGULATOR

Pipe Horizontal, vertical or inclined. May be surrounded by air, water, or soil; insulated or bare.


Equipment Devices (have no length)

Descriptions of the completion, fitting, process, and unit operation equipment devices available in PIPEPHASE are as follows:

Fittings

Process Equipment

Annulus Well annulus. Heat loss is simulated using an overall heat transfer coefficient and geothermal gradient.

Tubing Well tubing. Heat loss is simulated using an overall heat transfer coefficient and geothermal gradient.

Inflow Performance Relationship

Models the relationship between flowrate and reservoir pressure draw-down or pressure drop at the sand face in a well.

Completion Bottomhole completion, the interface between the reservoir and a well. There are two types of completion: gravel-packed and open-perforated.

Bend A standard mitred bend or non-standard bend with defined angle and radius.

Check valve Device that allows flow in only one direction.

Choke valve Restricts fluid flow. MCHOKE, a variant of CHOKE, introduces a discontinuity into a network which is solved using a special sub-networking method. PIPEPHASE calculates the choke size.

Contraction Reduction in diameter from larger to smaller pipe. Variable angle.

Entrance Entrance into a pipe from a larger volume such as a vessel.

Exit Exit from a pipe to a larger volume such as a vessel.

Expansion Increase in diameter from smaller to larger pipe. Variable angle.

Nozzle Flow restriction used in metering.

Orifice Orifice meter. Orifice plate can use thick or thin calculation formula.

Tee Tee piece. Flow may be straight on or through the branch.

Valve Any type of valve, e.g., gate, globe, angle, ball, butterfly, plug, cock.

Venturimeter Venturi flow meter.

Compressor Simple single or multispeed gas compressor.

Multistage Compressor

Rigorous single or multistage gas compressor with optional inlet pressure calculation. Uses a special sub-networking method. PIPEPHASE calculates the required horse power.

Cooler Removes heat from a stream.

DPDT Any device that changes pressure and/or temperature with flowrate.

Expander Steam expander.


Unit Operations

Flow Device Sizing

In a single link system, PIPEPHASE can calculate the sizes of pipes and tubings to meet either a pressure drop or a maximum velocity criterion.

With a fixed source pressure and fixed sink pressure, PIPEPHASE sizes all these devices to the same diameter.

With a fixed source or sink pressure and maximum velocity, PIPEPHASE sizes each device separately.

Gaslift Valve Well gaslift valve.

Heater Adds heat to a stream.

Injection Re-introduces a stream from a compositional separator back into a link.

Pump Single or multispeed liquid pump. An electric submersible pump may be modeled.

Regulator Means of fixing maximum pressure at any point in the structure. MREGULATOR, a variant of REGULATOR, introduces a discontinuity into a network which is solved using a special sub-networking method.

Separator Splits some or all of one of the fluid phases from a link.

Hydrates Predicts the temperature/pressure regime under which hydrates are prone to form.

Calculator A utility that allows you to compute results from flowsheet or network parameters. These results can then be used as optimizer constraints or objective parameters.


Pipe sizing You may ask for all flow devices to be sized or just selected ones.

p. 4-150 DEVICEp. 4-150 LINE

You may supply a set of maximum velocities and a corresponding set of diameters or slip densities.

p. 4-151 MAXV


Pressure Drop Calculations

PIPEPHASE calculates pressure drops for pipes, annuli and tubing. There are many methods for calculating pressure drops. You can define one method globally for use throughout the simulation, or you can use different methods in different pipes. Refer to the discussions Single-Phase Methods, p. A-2 and Two-Phase and Compositional Methods, p. A-2, for a survey of the pressure drop calculation methods available in PIPEPHASE.

The following table lists recommended pressure drop methods for single-phase flow in pipes with non-compositional fluids

The following table lists the pressure drop methods recommended for multiphase flow in horizontal and inclined pipes. A legend and comments are located below the table.


Pressure drop method

Choose a method that is appropriate to the type of fluid and piping topology you have. If you do not choose a method, PIPEPHASE will use Beggs & Brill-Moody for compositional, blackoil, condensate, or steam and Moody for non-compositional fluids.

p. 4-21 FCODE

You may choose a different method for an individual device. If you do not choose a method for a device, PIPEPHASE will use the method you selected globally.

p. 4-92 PIPEp. 4-94 ANNULUSp. 4-95 TUBINGp. 4-21 FCODE

Table 3-4: Pressure Drop Methods for Single-Phase Flow (Non-Compositional Fluids)

Liquid Gas

MoodyHazen-Williams

MoodyPanhandle BfWeymouthAmerican Gas Association

Table 3-5: Applicability of Multiphase Flow Correlations

Methods5

Horizontal and

inclines < 10o

Upward incline

10o<a<70o

Downward Incline

10o<a<70o

Vertical Upward

90o and > 70o

Vertical Downward

90o and> 70o

Beggs & Brill 4 4 4 4 4Beggs & Brill - Moody1 4 4 4 4 4Beggs & Brill - No slip 8 8 8 8 4Beggs & Brill - Moody-Eaton3 8 8 8 8 8Beggs & Brill - Moody-Dukler3 8 8 8 8 8Beggs & Brill - Moody-Hagedorn & Brown

8 8 8 8 8

Mukherjee & Brill2 8 4 4 8 8Mukherjee & Brill-Eaton3 8 8 8 8 8Ansari 8 8 8 4 8


1. In general, this method is recommended because it performs reasonably well for the widest range of flow conditions.

2. This method is recommended for pipelines with low liquid holdup in hilly terrain.

3. These non-standard hybrid models should be used only after matching measured data.

4. These models are available as add-ons through your SimSci representative

5. All these correlations were developed for circular flow cross-section. These correlations are used for Annulus flow using the wetted perimeter-hydraulic radius concept in place of the radius of the circular cross section.

Pressure Drop in Flow Devices

The pressure drop in a flow device (Pipe, Tubing or Annulus) of length L consists of three components: friction, elevation, and acceleration.

In general, the frictional pressure gradient may be expressed as:

(3-1)

where:

= fluid density

q = volumetric flux

d = equivalent diameter (actual diameter in the case of pipes and tubing)

Orkiszewski 8 8 8 4 8Duns & Ros 8 8 8 4 8Hagedorn & Brown 8 8 8 4 8Hagedorn & Brown - Beggs & Brill 8 8 8 8 8Aziz 8 8 8 4 8Gray (not applicable for Compositional)

8 8 8 4 8

Gray - Moody (not applicable for Compositional)

8 8 8 4 8

Angel - Welchon - Ross 8 8 8 8 4Eaton 4 8 8 8 8Eaton-Flannigan 4 4 4 8 8Dukler 4 8 8 8 8Dukler-Flannigan 4 4 4 8 8Lockhart & Martinelli 4 4 8 8 8Dukler-Eaton-Flannigan 4 4 4 8 8Olimens 4 4 8 8 8OLGA4 4 4 4 4 4TACITE4 4 4 4 4 4

Legend 4 Correlation recommended for the application8 Correlation allowed, but not recommended for the application

Table 3-5: Applicability of Multiphase Flow Correlations (cont.)

Methods5

Horizontal and

inclines < 10o

Upward incline

10o<a<70o

Downward Incline

10o<a<70o

Vertical Upward

90o and > 70o

Vertical Downward

90o and> 70o

dPdL-------

f

fq2

d5

-----------


The friction factor, f, is inversely proportional to the Reynolds number for laminar flow. For turbulent flow, f is a non-linear function of the Reynolds number and the pipe roughness.

In general, the elevation pressure gradient may be expressed as:

(3-2)

where:

= fluid density

= inclination angle

The acceleration pressure gradient is generally small, except when the fluid is compressible, and the velocity and velocity gradients in the pipe are high. In general, the acceleration pressure gradient may be expressed as:

(3-3)

where:

= fluid density

v = fluid velocity


Inside diameter and roughness

If the majority of your flow devices have the same inside diameter, you can specify a global inside diameter at the start of the simulation. Then you can override this value for those devices which do not conform to the default. Roughness can be specified also as a global parameter or for each device.

p. 4-24 DEFAULTp. 4-92 PIPEp. 4-94 ANNULUSp. 4-95 TUBING

Inclined pipes You can specify an elevation change or depth for each device If the elevation change equals the length, the device is vertical. If you do not specify an elevation change, PIPEPHASE assumes that pipes are horizontal and that annuli and tubings are vertical.

p. 4-92 PIPEp. 4-94 ANNULUSp. 4-95 TUBING

Acceleration terms

You may instruct PIPEPHASE to ignore the acceleration term in pressure drop calculations, if desired.

p. 4-20 CALCULATION

dPdL-------

e sin

dPdL-------

av

dvdx------


Nominal Diameter and Pipe Schedule

As an alternative to entering a pipe (or tubing) inside diameter, you can specify a nominal diameter and a schedule. PIPEPHASE has an internal database of standard nominal pipe sizes and pipe schedules; the allowed combinations of nominal diameter and schedule in this database are detailed in Table 3-6. You may supply your own database which PIPEPHASE will use instead of its own.

To specify nominal diameter and schedule for...

See...

All devices as a global value

You may supply a nominal diameter and schedule that will be used for all the fittings in this table, unless overridden by data in the input to the fitting itself.

p. 4-24 DEFAULT

Your pipes and fittings

You may create a database of nominal diameters and pipe schedules and have PIPEPHASE use it instead of its own internal database

p. 4-24 DEFAULT

Pipe You may supply a nominal diameter and schedule. p. 4-92 PIPE

Tubing You may supply a nominal diameter and schedule. p. 4-95 TUBING

Bend You may supply a nominal diameter and schedule. p. 4-124 BEND

Entrance You may supply a nominal diameter and schedule for the downstream pipe.

p. 4-129 ENTRANCE

Exit You may supply a nominal diameter and schedule for the upstream pipe.

p. 4-130 EXIT

Nozzle You may supply a nominal diameter and schedule for the upstream pipe.

p. 4-132 NOZZLE

Orifice You may supply a nominal diameter and schedule for the upstream pipe.

p. 4-133 ORIFICE

Tee You may supply a nominal diameter and schedule for the upstream pipe.

p. 4-133 TEE

Valve You may supply a nominal diameter and schedule for the upstream pipe.

p. 4-134 VALVE

Venturi You may supply a nominal diameter and schedule for the upstream pipe.

p. 4-136 VENTURIMETER

Contraction You may supply a nominal diameter and schedule for the inlet and outlet pipes.

p. 4-128 CONTRACTION

Expansion You may supply a nominal diameter and schedule for the inlet and outlet pipes.

p. 4-131 EXPANSION


Pressure Drop in Completions

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

PIPEPHASE uses the Jones model for gravel-packed completion and the McCleod model for open-perforated completions. For further information about these models, please refer to Chapter 5, Technical Reference.

Table 3-6: Allowable Pipe Nominal Diameters and Schedules

Nominal Diameter (Inches) Valid Pipe Schedule Numbers

0.125 40 800.250 40 800.375 40 800.5 40 80 1600.75 40 80 1601.00 40 80 1601.25 40 80 1601.5 40 80 1602.0 40 80 1602.5 40 80 1603.0 40 80 1603.5 40 804.0 40 80 120 1604.5 405.0 40 80 120 1606.0 40 80 120 1608.0 10 20 30 40 60 80 100 120 140 16010.0 10 20 30 40 60 80 100 120 140 16012.0 10 20 30 40 60 80 100 120 140 16014.0 10 20 30 40 60 80 100 120 140 16016.0 10 20 40 60 80 100 120 140 16018.0 10 20 30 40 60 80 100 120 140 16020.0 10 20 30 40 60 80 100 120 140 16024.0 10 20 30 40 60 80 100 120 140 16030.0 10 20 30


Figure 3-1: Jones Model

Figure 3-2: McLeod Model

Pressure Drop in Fittings

The general form of the pressure drop equation is:

(3-4)


Completion You may define a completion as being gravel packed (Jones) or open perforated (McLeod).

p. 4-101 COMPLETION

Dual Completion

You may model dual completions, both concentric and parallel.

p. 4-98 Dual Completions

P KG2

2g----------------=


where:

P = pressure drop across the fitting

K = resistance coefficient/ K-factor

G = mass velocity (mass flowrate/flow area)

= two-phase pressure drop multiplier

g = acceleration due to gravity

= fluid density (equal to liquid density for two-phase flows)


Bend, tee, valve

PIPEPHASE uses the generalized pressure drop equation with a resistance coefficient. For bends, tees, and valves, you can either supply the resistance coefficient directly or supply an equivalent length and have PIPEPHASE calculate the resistance coefficient as a function of the friction factor.

p. 4-124 BENDp. 4-133 TEEp. 4-134 VALVE

Entrance, exit For entrances and exits you can supply the resistance coefficient or use the default value.

p. 4-129 ENTRANCEp. 4-130 EXIT

Contraction, expansion, nozzle, orifice, Venturi

For contractions, expansions, nozzles, orifices, and Venturimeters, you can supply the resistance coefficient or use the value that PIPEPHASE calculates from its built-in correlations. These correlations relate the resistance coefficient to the Reynolds number and specific fitting parameters such as orifice diameter, Venturi throat diameter, contraction and expansion angles, and nozzle diameter. For gas flow in nozzles, orifices, and Venturimeters, the specific heat ratio is also used in the calculation of the resistance coefficient.

p. 4-132 NOZZLEp. 4-131 EXPANSIONp. 4-136 VENTURIMETERp. 4-128 CONTRACTIONp. 4-133 ORIFICE

Choke The pressure drop for a choke is calculated by the orifice method for a single-phase fluid or by the various choke models for a two-phase fluid. You can supply a discharge coefficient or use the default value. MCHOKE, a variant of CHOKE which introduces a discontinuity into a network, uses the Fortunati model only.

p. 4-125 CHOKEp. 4-127 Besides the fluid type, a more general approach for choosing choke models in a network system are:

Check valve A valve that permits flow in one direction only. You can supply a resistance coefficient or use the default value.

p. 4-125 CHECK


Equipment Items

PIPEPHASE simulates the change in fluid conditions across items of process equipment that typically appears in pipeline systems.

Two-phase correction in fittings

The pressure drops for fittings are corrected for two-phase flow by using either the Homogeneous flow model or the Chisholm model. If you do not make a selection, PIPEPHASE will use the default method. You may supply values for the Chisholm parameters.

p. 4-124 BENDp. 4-130 EXITp. 4-129 ENTRANCEp. 4-134 VALVEp. 4-133 TEEp. 4-128 CONTRACTIONp. 4-131 EXPANSIONp. 4-132 NOZZLE p. 4-133 ORIFICEp. 4-136 VENTURIMETER


Compressor A compressor imparts work to a gas. You supply either a known power or a known outlet pressure, and PIPEPHASE calculates the unknown parameter. You may impose a maximum value on the unknown parameter, and PIPEPHASE will constrain the calculations according to whichever parameter is limiting. Alternatively, you can supply a curve of flowrate against head. You may also supply an adiabatic efficiency as either a constant or a curve against head. The exit temperature is then determined by energy balance. If you specify more than one stage, PIPEPHASE interprets the curve to be for each stage; any maximum power you specify is over all of the stages rather than for each individual stage. You can also reference the compressor curve to a previously defined performance curve.

p. 4-102 COMPRESSOR

Multispeed Compressor

You can specify different compressor curves for up to five compressor speeds.

p. 4-102 COMPRESSOR

Multistage Compressor

In a multistage compressor you may specify different parameters curves, efficiencies, etc. for different stages. You may have multiple compressor trains, each train with multiple stages. You may have interstage scrubbers with downstream re-injection and interstage coolers and piping losses. You may specify the compressors inlet pressure. When you do this, PIPEPHASE invokes a special algorithm which breaks the flowsheet at the compressor inlet, and solves the resulting subnetworks so that the pressures match at the interface. PIPEPHASE calculates the compressor power that is required for the pressures to match.

p. 4-103 MCOMPRESS



Cooler The cooler removes heat from the system. You supply either a known exit temperature or known duty of the unit, and PIPEPHASE will calculate the unknown parameter. You may impose a maximum (for duty) or minimum (for temperature) value on the unknown parameter, and PIPEPHASE will constrain calculations according to whichever parameter is limiting. (Pressure drop as a function of flowrate can be modeled.)

p. 4-105 COOLER

Steam expander

The expander models the expansion of steam from a high pressure to a low pressure. You may specify the power required, or the pressure drop or the pressure ratio. If the unit is in a spur link, you may alternatively specify the outlet pressure.

p. 4-106 EXPANDER

Gaslift valve This unit simulates the presence of a gaslift valve as part of a well link. You must define the properties of the lift gas in the PVT data section.

p. 4-107 GLVALVE p. 4-59 LIFTGAS (Blackoil only)

General purpose DP and DT unit

The DPDT unit is a general purpose unit for defining a pressure and/or temperature difference at a point in the piping structure. You can use this unit to model any equipment device where the pressure difference and temperature difference characteristics can be represented as curves against flowrate. You may also specify the flow versus pressure drop equation for the curve.

p. 4-105 DPDT

Heater The heater adds heat to the system. You supply either a known exit temperature or known duty of the unit, and PIPEPHASE will calculate the unknown. You may impose a maximum value on the unknown parameter, and PIPEPHASE will constrain the calculations according to whichever parameter is limiting. (Pressure drop as a function of flowrate can be modeled.)

p. 4-107 HEATER

Injection The injection introduces a stream into a link. The stream comes from a separator (see the entry below). You may fix the pressure and temperature of the injected stream.

p. 4-108 INJECTION



Pump A pump imparts work to a liquid. You supply either a known power or a known outlet pressure, and PIPEPHASE calculates the unknown. You may impose a maximum value on the unknown parameter, and PIPEPHASE will constrain the calculations according to whichever parameter is limiting. Alternatively, you can supply a curve of flowrate against head. You may also supply an efficiency as a constant or as a curve against head. The exit temperature is determined by energy balance.If you specify more than one stage, PIPEPHASE interprets the curve to be for each stage; any maximum power you specify is over all of the stages rather than for each individual stage. You can also reference the pump curve to a previously defined performance curve.

p. 4-119 PUMP

Multispeed pump

You can specify different pump curves for up to five pump speeds.

p. 4-119 PUMP

Electric submersible pump

An extension of the PUMP item allows you to model an electric submersible pump. In addition to all the features mentioned above, you may supply motor horsepower as a curve, either in tabular form or as coefficients of an equation. You may specify auxiliary power to be supplied to the pump. You may specify head degradation as a function of gas ingestion percentage, plus minimum submergence, casing head pressure, and vertical pressure gradient in the casing-tubing annulus due to the gas column. Refer also to Separator, below. You can also reference the electric submersible pump curve to a previously defined performance curve.

p. 4-119 PUMP

Regulator The regulator is used to set the maximum pressure at some point in the pipeline structure. It allows flow in only one direction and can be used to prevent flow reversal within a selected link in a network.

p. 4-121 REGULATOR

Subnetwork regulator

You may specify the inlet pressure of this item. When you do this, PIPEPHASE invokes a special algorithm which breaks the flowsheet at the inlet and solves the resulting subnetworks so that the pressures match at the interface. You may also specify the flowrate through the regulator.

p. 4-128 MREGULATOR



Heat Transfer Calculations

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

The general equation for heat transfer from a flow device is:

(3-5)

where:

Q = rate of heat transfer per unit length

U = overall heat transfer coefficient

Separator The separator splits out all or part of the gas or liquid phase of a multiphase fluid. In the case of a hydrocarbon system with water, you can select the hydrocarbon or aqueous phase instead of the total liquid phase. You specify the amount separated as an absolute flowrate or as a percentage of the phase. You can separate more than one phase in one separator. You can then reinject the separated streams at points downstream in the link using the Injector. You cannot impose a pressure drop on the separator.

p. 4-122 SEPARATOR

Bottomhole separator

If a separator is positioned at the bottomhole below an electric submersible pump, you may either specify gas injection percentage or supply pump dimensions and have PIPEPHASE calculate it.

p. 4-122 SEPARATOR

Hydrates Hydrates are solid mixtures of water and other small molecules. Under certain process conditions, particularly in the gas processing industry, hydrate formation may clog lines and foul process equipment. The HYDRATE unit operation predicts the pressure and temperature regime in which the process is vulnerable to hydrate formation. Calculations performed assume the presence of free water for hydrates to form. Possible hydrate formers include: methane through isobutane, carbon dioxide, hydrogen sulfide, nitrogen, ethylene, propylene, argon, krypton, xenon, cyclopropane, and sulfur hexafluoride. The effect of sodium chloride, methanol, ethylene glycol, di-ethylene glycol, and tri-ethylene glycol hydrate inhibitors can also be studied.

p. 4-144 HYDRATES


Q UAT=


A = surface area per unit length

T= temperature difference between bulk fluid and outside medium

The overall heat transfer coefficient either is input or may be calculated from the constituent film coefficients and geometries.

For annuli, you must specify an overall heat transfer coefficient.

For a pipe or tubing, you may supply an overall coefficient or you may request detailed heat transfer calculations. Detailed heat transfer calculations are invoked when you input any one of the parameters required to carry out the calculations.

Detailed Heat Transfer in Pipe and Tubing

For a pipe surrounded by soil, water, or air, you define the medium properties (and velocity of water or air). For a buried pipe, you enter the buried depth.

For tubing you enter data that describe the properties of the annuli and casings between the outside of the tubing and the inside of the hole.


Pipe and tubing You may specify an overall coefficient or the properties of the surrounding medium. You also supply the ambient temperature or geothermal gradient. For piping only, you can supply these values globally for all devices or for individual devices.

p. 4-24 DEFAULTp. 4-92 PIPEp. 4-95 TUBING

Annuli You specify the overall heat transfer coefficient and the geothermal gradient. You can supply these values globally for all devices or for individual devices.

p. 4-24 DEFAULTp. 4-94 ANNULUS

Isothermal calculations

For non-compositional gas or liquid fluid models, you may suppress heat transfer calculations for individual flow devices.

p. 4-92 PIPEp. 4-95 TUBINGp. 4-94 ANNULUS


Gaslift Analysis

Gaslift analysis is used to investigate the effects of lift gas on well production. Gaslift can be used with blackoil wells where the oil production is upward through the well tubing and the lift gas is injected downward through the well casing.

Note: If you want to simulate the effect of gaslift with a compositional fluid, use the INJECTION device.

There are four options for gaslift analysis:

1. Generate the pressure profile for a fixed oil production and lift gas rate.

2. Generate a table of oil production versus lift gas rate for fixed pressures.

3. Locate the gas injection valve to match required tubing head pressure.

4. Locate the gas injection valve to match required casing head pressure.


Calculation type You must specify that you want to do a gaslift simulation.

p. 4-20 CALCULATION

Fluid Properties You must specify the fluid properties of the Blackoil. You must specify the fluid properties of the lift gas.

p. 4-57 SET for Blackoilp. 4-59 LIFTGAS (Blackoil only)

Structure Data You must specify the oil production data. You must have a production string link with the name PROD. This link will contain well and surface devices. For Option 4, only Tubing is allowed.

p. 4-75 SOURCEp. 4-89 LINK

You must have an injection string link with the name GASL. This link may contain only annuli.

p. 4-89 LINKp. 4-94 ANNULUS

Gaslift Data You must input gaslift data according to the option you have selected. Option 1.Generate a pressure profile for a fixed oil production and lift gas rate.

p. 4-147 PCALC

Option 2.Generate a table of oil production versus lift gas rate for fixed pressures.

p. 4-148 CAPACITY

Option 3.Locate the gas injection valve to match required tubing head pressure.

p. 4-148 LOCATION

Option 4.Locate the gas injection valve to match required casing head pressure.

p. 4-148 LOCATION


Sphering or Pigging

PIPEPHASE’s sphering calculations predict the quantity of liquid formed when a multiphase fluid flows in a pipeline and determine the size of the liquid slug that is pushed out when the pipe is pigged.

Sphering calculations can be carried out for single links. The launching station is at the inlet of a pipe. You may have intermediate launching stations; a sphere is launched from a pipe when the previous sphere(s) reach the inlet of that pipe.

Reservoirs and Inflow Performance Relationships

Using PIPEPHASE, you can examine the effect of reservoir conditions on the performance of wells and downstream networks. You can also investigate the implications of declining reservoir pressure and production rate and shut-in wells when a user-specified water cut or gas-oil ratio is exceeded.

The Inflow Performance Relationship device models the relationship between flowrate and reservoir pressure drawdown or pressure drop at the sand face in a well.


Calculation type You must specify that you want to do a sphering simulation.

p. 4-20 CALCULATION

Fluid type The fluid must be compositional and both gas and liquid should be present to obtain realistic results.

p. 4-20 CALCULATION

Time Increments You may override the default time step used in the McDonald-Baker successive steady-state calculation method.

p. 4-26 SEGMENT

Structure Data You may have only PIPE devices. You identify a pipe with a launching station by specifying a sphere diameter on the PIPE statement. The first launching station must be in the first pipe of the link.

p. 4-92 PIPE


Type of model You may select from five standard models. You may write your own subroutine and use it to model the inflow performance relationship.

p. 4-109 IPR

Reservoir curves You may enter tables of reservoir pressure, cumulative production, Gas-Oil Ratio, Condensate-Gas Ratio, Water Cut, and Water-Gas ratio. These are used in Time-stepping to simulate reservoir decline with time.

p. 4-109 IPR

Multiple reservoirs and multiple wells

You can have multiple reservoirs in one network. One reservoir can serve several wells.

p. 4-109 IPR


Production Planning and Time-Stepping

Production planning involves the study of the time-dependent interactions between the producing formation(s) and all of the wells, gathering lines, and surface facilities in an oil or gas field. PIPEPHASE supplies this capability through its Time-stepping feature.

Typically, the study extends from a few years to the entire producing life of the field. For such extended periods, a quasi-steady state approach provides an efficient representation of the time-dependency. Time-stepping carries out a series of steady-state PIPEPHASE simulations automatically in the same run. Each simulation represents the conditions at a specific time-step in the operating history of the field.

Time Changes

The changes supported are similar to the Case Study.

Wells and Well Grouping

Each of the well completion zones in a gathering network produces from a specific formation or reservoir. The decline in the reservoir pressure with time and the changes in the characteristics of the fluid produced are a function of the total fluid volume produced from the reservoir. For the purposes of these calculations, a well completion is associated with a reservoir group. A reservoir group includes all of the producing zones that contribute to its depletion.

Automatic subsurface networks

You may automatically create a subsurface network for a well with multiple sources. PIPEPHASE solves these using a finite difference solution method. This is a quicker but less rigorous method of creating a subsurface network. Refer to Subsurface Networks and Multiple Completion Modeling later in this chapter for further details.

p. 4-109 IPR

IPR curves You may enter curves that correlate reservoir pressure or cumulative production with flowing bottomhole pressure and flowrate. These data are then regressed onto one of the standard models.

p. 4-109 IPR

Pseudo-pressure formulation

For an IPR with a gas basis, you may specify a drawdown formulation.

p. 4-109 IPR


Selecting times Supply a series of times. PIPEPHASE will carry out simulations at each of those times.

p. 4-109 IPR

Downstream network changes

At each time you may specify one or more changes to the network or conditions downstream of the well.

p. 4-109 IPR



Reservoir Depletion

The depletion of a reservoir over the life of a field is characterized by a decline in average reservoir pressure and changing fluid composition. For most reservoirs, the gas-oil ratio increases with time; for a reservoir with an active water drive, the produced water cut increases as the water table creeps up.

Facilities Planning

In a gathering system, changes to the operation of surface facilities directly affect the overall production. For example, adding compression facilities to an existing gas gathering network reduces the pressure at the upstream wells, which in turn increases the drawdown and results in improved production from the reservoir; an increase in the separator pressure will have the opposite effect. Time-stepping enables you to simulate changes to the facilities installation over time.


Reservoir Groups You must name the reservoir GROUP and supply depletion data in one IPR device. Other IPR devices may access the same reservoir depletion data by using the same GROUP name.

p. 4-109 IPR

Depletion characteristics

Supply a curve of reservoir pressures against cumulative production.

p. 4-109 IPR

Gas and gas condensate fields

For a gas or gas condensate field you may supply the slope of the depletion curve as pressure decline rate per unit of production.

p. 4-109 IPR

Production decline rates for each IPR

The production decline characteristics for individual completion zones must be defined. Tabular data represent the decline in the flowing well pressure as a function of the production rate. The time-dependent parameter may be expressed in terms of reservoir pressure or cumulative production.

p. 4-109 IPR

Fluid compositional changes

You may enter curves for water cut, gas-oil ratio (or condensate-gas ratio for condensate wells), and water cut (or water-gas ratio for condensate wells) as functions of reservoir pressure or cumulative reservoir produced volume.

p. 4-109 IPR


Subsurface Networks and Multiple Completion Modeling

A Single Well

A single well can produce from one reservoir:

Figure 3-3: One Well, One Reservoir:


A source to give the properties, flowrate, and conditions of the fluid. p. 4-75 SOURCE

One IPR to define the interface to the reservoir. p. 4-109 IPR

One tubing from the well to the surface. p. 4-95 TUBING

One node to continue into the rest of the network. p. 4-88 JUNCTIONp. 4-87 SINK


A source for each reservoir to give the properties, flowrates, and conditions of the fluids.

p. 4-75 SOURCE

An IPR for each reservoir to define the interfaces. p. 4-109 IPR

A tubing between consecutive reservoirs. p. 4-95 TUBING

A tubing from the last reservoir to the surface. p. 4-95 TUBING

A node to continue into the rest of the network. p. 4-88 JUNCTIONp. 4-87 SINK

Tubing

Ground Level

Junction or sink

ReservoirIPR


Figure 3-4: One Well, More Than One Reservoir

More Than One Well

You may have more than one well in a PIPEPHASE run. The wells may all use one reservoir. In this case, information for the reservoir data is entered in one IPR and accessed from other IPRs using the GROUP name.

Multiple Completions

In PIPEPHASE you may model a multiple completion rigorously:


A source for each completion to give the properties, flowrates, and conditions of the fluids.

p. 4-75 SOURCE

An IPR for each completion to define the interfaces. p. 4-109 IPR

Tubing and junctions to form the network between completions. p. 4-95 TUBING

A tubing from the last completion to the surface. p. 4-95 TUBING


Tubing

Ground Level

Reservoir

Tubing

Reservoir

Junction or sink

IPR

IPR

Subsurface junction


Figure 3-5: Multiple IPRs

Alternatively, you may approximate these conditions by having PIPEPHASE automatically generate a subsurface network:

Figure 3-6: One IPR, Automatic Multiple Completions

Case Studies

The CASE STUDY option provides the facility to perform parametric studies and to print multiple problem solutions in a single computer run. Case studies are always performed after the base case problem has been solved. If the base case problem cannot be solved for any reason, then no case studies are performed. Each case study analysis is performed based on the cumulative changes to the flowsheet up to that time.


One source to give the properties, flowrates and conditions of the fluids. p. 4-75 SOURCE

One IPR with physical dimensions such as length, inclination. p. 4-109 IPR

A tubing from the IPR to the surface. p. 4-95 TUBING


Reservoir

IPR1 IPR2 IPR3

Tubing

Ground Level

Junction or sink

Subsurface junctions

Reservoir

Length of well

S 1 S 2 S 3

Internally generated sources

IPR

Tubing

Ground Level

Junction or sink


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

There is no limit on the number of CHANGE statements per case study or on the total number of case studies that may be in a given run. The cumulative changes up to a given case study run may be erased and the original base case restored at any time.

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

Global Changes

You may change one parameter in the entire problem.You may specify an old value so that only those specified parameters with that old value will be changed. Otherwise, all values will be changed. You may also change parameters for all devices in a link. In this case, the old value cannot be used to limit the changes.

Individual Changes

Source, sink, and device parameters may be changed individually. You must specify a name for each source, sink, or device where a parameter change is desired.

To... See...

Add descriptive text You can add one line of description for each case study.


Make changes You can change any of the parameters in Table 3-6, either globally or on individual flow elements.

p. 4-154 PARAMETER

You can restore the base case at any time. p. 4-154 RESTORE


Nodal Analysis

Nodal (Sensitivity) Analysis allows you to study the overall performance of wells, pipelines and other single link systems as a function of input parameters and flowrates. The results are summarized in tabular and graphical form. You can also study combinations of inflow and outflow parameters using the multiple combination nodal analysis option.

Nodal Analysis is performed on a single link.

Dividing the Link

You first divide your single link into two sections, separated by a Solution Node. The section upstream of the Solution Node is called the Inflow section and would typically be the tubing of a well. The section downstream of the Solution Node is called the Outflow section and would typically be the flowline from the wellhead to a surface separator. The Solution Node, in this case, would be the well-head node.

If you locate the Solution Node actually at the source or the sink, then there will be only an Outflow or Inflow section respectively.

If you do not want to vary any parameters in either the Inflow section or the Outflow section, simply omit the INFLOW or OUTFLOW statement. Obviously, a Nodal Analysis cannot be carried out without at least one of these statements.

Selecting Parameters and Flowrates

You then select a parameter in the Inflow section and a parameter in the Outflow section. Typical parameters would be reservoir pressure (for Inflow) and pipe ID (for Outflow). You may enter up to five values for each of these parameters. Each combination of Inflow parameter value and Outflow parameter value represents an operating point of the system. This means that there may be up to 25 operating points.

The parameters you select must have values supplied in the base case input data.

Finally, you define up to ten flowrates.

Sensitivity Results

PIPEPHASE calculates the flowrates and Solution Node pressures corresponding to each operating point and prints them out in the form of tables and plots. The flowrates you input must span all the flowrates at which you expect the operating points to occur.


Grouping Parameters

As an extension to the Nodal Analysis feature, PIPEPHASE allows you to group a number of variables into one nodal parameter. For example, you may define an Outflow parameter as a combination of pump power, pipe ID and heater temperature. Each of the five values of the Outflow parameter would now be a combination of the corresponding values of each of the contributing variables.

Thus you might define that the first value of the Outflow parameter is the combination of 25KW pump power with 30 mm pipe ID and 400 K; the second 30KW, 40 mm and 310 K; the third 35KW, 50 mm and 350 K; and so on.

The following table lists the variables that are available for nodal analysis

To... See...

Add descriptive text

You can add one line of description for each of the Inflow and Outflow sections.


Define the Solution Node

You must define a Solution Node which comes between the Inflow and Outflow sections. If you want the Solution Node to be at the flowing bottomhole of an injection well, use BOTTOMHOLE. If you want to locate the Solution Node at the outlet of the last device and want to use Sink pressure as a variable parameter, use SINK.

p. 4-175 NODE

Define the parameter(s)

You must define at least one Inflow or Outflow parameter for PIPEPHASE to change. The parameters that are accessible are divided into seven categories, as defined in the table below. If you want to define a nodal parameter as a group of variables, you may combine up to ten variables within one Category. You may not combine variables in different categories.

p. 4-176 INFLOWp. 4-179 OUTFLOW


Table 3-7: Variables Available for Nodal Analysis.

Category Device Variable

Category 1 - Source SOURCE NAMEPRESSURECOEFFICIENTEXPPIVOGEL

Category 2 - Sink SINK NAMEPRESIICOEFFEXP

Category 3 - Devices PIPE NAMEIDROUGHNESSUFLOWEFF

TUBING NAMEIDROUGHNESSUFLOWEFF

ANNULUS NAMEIDANNODTUBROUGHNESSUFLOWEFF

COMPRESSOR/PUMP

NAMEPOWERPRESSUREEFFICIENCYSTAGES

HEATER/COOLER NAMEDUTYTOUTDP

CHOKE NAMEIDCOEFFICIENT

SEPARATOR NAMERATEPERCENT

GLVALVE NAMERATEDISSOLVE


INJECTION NAMETEMPERATUREPRESSURE

COMPLETION NAMEPENETRATIONPERFDSHOTSTUNNEL

Category 4 - Non-compositional Source Properties

GORWCUTCGRWGRQUALITY

Category 5 - Main Source COMPOSITION

Category Device Variable


Chapter 4 Input Reference

Chapter Contents

About This Chapter . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6Categories of Input. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7

Order of Categories. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7Keywords . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8

Keyword Input . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8Qualifiers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8Commenting Input . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9Default Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9Units of Measurement . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10

Basis of Measurements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10Multiple Units of Measurement . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10Continuing Statements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11Layout of Input . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11

Input Statement Descriptions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11Legend . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11

GENERAL Data Category of Input . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13Global Parameters. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13TITLE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14DESCRIPTION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14DIMENSION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14CALCULATION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 20FCODE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 21DEFAULT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 24SEGMENT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 26LIMITS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 28PRINT. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 28OUTDIMENSION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 31

COMPONENT Data Category of Input. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 32Overview. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 32COMPONENT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 33


LIBID . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 34PETROLEUM . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 34ASSAY. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 35CUTPOINTS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 37MW. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 37SPGR . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 37API . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 37ACENTRIC . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 37ZC. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 37TC() . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 37PC(). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 37NBP() . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 37STDDENSITY(). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 37VC. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 38VP() . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 38ENTHALPY() . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 38CP(). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 38LATENT() . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 38DENSITY() . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 38VISCOSITY(). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 38CONDUCTIVITY() . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 38SURFACE() . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 38

NETWORK Data Category of Input . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 40Overview . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 40NETWORK . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 40SOLUTION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 40TOLERANCE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 44ACCELERATION (for PBAL Network Method Only) . . . . . . . . . . . . . . . . . . . . . . . . . 44

THERMODYNAMIC Data Category of Input . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 46Overview . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 46THERMODYNAMIC . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 48METHOD. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 48WATER . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 52BWRS. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 53LKP. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 53PR . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 53SRK . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 53

PVT Data Category of Input . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 54Overview . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 54PVT. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 54SET. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 54SET for Non-Compositional Liquid. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 55SET for Non-Compositional Gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 55SET for Steam . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 55SET for Compositional Fluid . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 56SET for Condensate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 56SET for Compositional Blackoil (Compositional sets only) . . . . . . . . . . . . . . . . . . . . . . 57SET for Blackoil. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 57

4-2 Input Reference

ADJUST (Blackoil only) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 58LIFTGAS (Blackoil only). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 59TABULAR (Blackoil only) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 59FVF (Blackoil only) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 60SGOR() (Blackoil only) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 61VISCOSITY() (Blackoil only) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 61GRAVITY() (Blackoil only) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 61CORRELATION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 62DIMENSION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 64GENERATE (for Compositional) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 65GENERATE (for Blackoil) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 66FILE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 70FILE (for Blackoil) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 70

STRUCTURE Data Category of Input . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 71Overview. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 71STRUCTURE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 75System Nodes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 75SOURCE. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 75CSOURCE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 78WTEST . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 80Distillation Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 81Gravity Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 82Molecular Weight . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 83LIGHTENDS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 83SINK . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 87JUNCTION. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 88LINK. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 89Flow Devices (have length) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 92PIPE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 92ANNULUS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 94TUBING . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 95Dual Completions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 98Parallel Dual Completions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 99Equipment Devices (have no length) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 101COMPLETION. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 101COMPRESSOR . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 102MCOMPRESS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 103COOLER . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 105DPDT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 105EXPANDER . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 106GLVALVE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 107HEATER. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 107INJECTION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 108IPR . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 109PUMP . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 119REGULATOR . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 121SEPARATOR . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 122BEND . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 124


CHECK. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 125CHOKE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 125MCHOKE. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 127MREGULATOR . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 128CONTRACTION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 128ENTRANCE. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 129EXIT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 130EXPANSION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 131NOZZLE. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 132ORIFICE. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 133TEE. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 133VALVE. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 134VENTURIMETER. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 136

UNIT OPERATIONS Data Category of Input . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 137Overview . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 137UNIT. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 138CALCULATOR . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 138DIMENSION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 139

CONSTANT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 139DEFINE. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 140RESULT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 140PROCEDURE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 141RETURN. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 144

HYDRATES. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 144EVALUATE. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 145

GASLIFT Category of Input . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 146Overview . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 146

GASLIFT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 147PCALC . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 147CAPACITY. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 148LOCATION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 148

SIZING DATA Category of Input. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 150Overview . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 150SIZING . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 150DEVICE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 150LINE. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 150MAXV . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 151

TIME-STEPPING Data Category of Input . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 152TIMESTEPPING . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 152CHANGE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 152

CASE STUDY Data Category of Input. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 154Overview . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 154CASESTUDY. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 154DESCRIPTION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 154RESTORE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 154PARAMETER . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 155Sources . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 155Sinks . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 160

4-4 Input Reference

Junctions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 164Pipe . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 168Tubing. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 169Annulus. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 170Compressors . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 171Pumps . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 171Heater . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 172Cooler . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 172Completion . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 173Gaslift Valves . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 173Chokes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 173Separators . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 174Regulators . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 175Expanders . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 176Valves . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 176Injection . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 177DPDT Device . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 177MCOMP . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 178Bend . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 179Check Valve . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 179Contraction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 180Entrance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 180Exit . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 180Expansion . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 181Nozzle . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 181Orifice . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 182Tee . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 182IPR . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 183Calculator Unit . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 183Optimization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 184Objective Parameter . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 184Constraint Variable . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 185Decision Variable . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 185PVT Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 186Network Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 186LINK. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 187

SENSITIVITY ANALYSIS Data Category of Input . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 189Overview. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 189SENSITIVITY . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 189NODE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 189DESCRIPTION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 190INFLOW. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 190OUTFLOW. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 193FLOW . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 193

PSPLIT Data Category of Input. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 194PSPLIT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 194TABLE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 194

User-Defined DP Correlations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 195


FORTRAN Standards. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 195User Subroutine Specifications . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 196Saving Data for Output. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 199PIPEPHASE Flash Routine Interface. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 200Moody Friction Factor Interface . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 201Examples . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 201

Example 1 – Olimen’s Pressure Drop . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 202Example 2 – Fancher and Brown Pressure Drop . . . . . . . . . . . . . . . . . . . . . . . . . . 204

User-Defined Viscosity Correlation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 206Implementing the Correlation. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 206User Subroutine Specifications . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 206Common Blocks . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 207

Inflow Performance Relationship (IPR) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 211User-Defined IPR . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 211Built-in Variable List . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 211Keyword Input . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 211Subprogram Structure. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 212Common Blocks . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 212Data Extraction. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 213Units Conversion Utility. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 213Calculation Utilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 214Secondary Output Utility . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 215Example Implementation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 215Variables and Arrays for User-Defined IPR Models . . . . . . . . . . . . . . . . . . . . . . . . . . . 217

Real Variables . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 217Indexed Real Variables . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 218Integer Variables . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 219Arrays . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 220

About This Chapter

This chapter contains information about the data that PIPEPHASE needs to perform different types of simulation. These data are input in a free format style file and the file is divided into categories; for example, Component Data, Property Data, etc.

This chapter explains the general rules for input, which categories are mandatory and which are optional. It defines all the terms used in the input descriptions and the conventions used throughout this chapter.

Each data category, the statements contained in it and the keywords on each statement are then described. For an explanation of how the program uses these data, please refer to Chapter 3, Using PIPEPHASE, and Chapter 6, Technical Reference.

4-6 Input Reference

Categories of Input

The data required by PIPEPHASE are input to the program in the following main categories.

Note: For Network Data GUI, the RESET function is not supported.

Which categories are mandatory and which are optional depend on what fluid type you have:

Table 4-1: Categories of Input

There are several other categories which can be selectively overridden on the flow device and fitting statements in the Structure Data Category of input.

Order of Categories

The only restriction on order of data input is that the General Data Category must be first. However, it is always good practice to maintain a consistent order. The order of the categories above, which is followed in this chapter, is recommended.

General Data Category Define general problem administration and global settings that control the whole flowsheet.

Component Data Category Define all components present in the feed streams.

Network Data Category Define calculational and network solution methods.

Thermodynamic Data Category Define the thermodynamic property methods used in the simulation.

PVT Data Category Define the properties of streams.

Structure Data Category Define the sources, junctions, sinks, flow devices, fittings and items of process equipment in the flowsheet.

Unit Operations Category Define the unit operations (e.g., the hydrates unit) included in the simulation.

Fluid Type Mandatory Categories Optional Categories

Non-Compositional GENERAL, PVT, STRUCTURE NETWORK

Compositional GENERAL, COMPONENT, THERMODYNAMIC, STRUCTURE

PVT, NETWORK, UNIT OPERATIONS

Gaslift Define data and options for blackoil well gaslift analysis.

Line Sizing Determine pipe sizes in single-link calculations.

Sensitivity (Nodal) Analysis

Study overall performance in single-link calculations as a function of one or two system parameters.

Case Study Change parameters and re-run.

Time-Stepping Data Allows the simulation of the effect of reservoir pressure decline with cumulative production on the network performance, and device parameter changes with time.


Keywords

Keyword Input

The primary mode for entering input in PIPEPHASE is in the form of keyword-controlled, free format statements. The keyword entries in a statement are separated by commas. For example:

PIPE ID=1.25, LENGTH=25, ROUGHNESS=0.002

For ease of interpretation, each keyword is an engineering word. To make the input easier to enter, any keyword with more than four characters can be truncated to a minimum of four characters. Keywords with fewer than four characters may not be lengthened. For example:

The keyword LENGTH may be written LENG.The keyword ROUGHNESS may be written ROUGH. The keyword ID cannot be written IDIA.

Keywords can stand alone, indicating that they are acting as a switch, or they can be associated with a value or another keyword by the use of an equals sign (=). This value can be entered in integer, decimal, or scientific format. For example:

In the instructions presented in this chapter, the presence of an equals sign (=) after a keyword means that PIPEPHASE expects a value or another keyword. In some cases, however, more than one data item is required. When this situation arises, the instructions will include the format for the data input. For example:

Qualifiers

Many keywords can be qualified by entering a keyword in brackets (parentheses) after them. The most common use of a qualifier is for defining a unit of measurement to override the set of units declared globally in the General Data Category of input. Other qualifiers include the definition of estimates, maxima and minima, fluid type and basis of a composition or flowrate. Some qualifiers are optional and some are mandatory. You may use more than one qualifier for a keyword and the order in which they appear is not important.

ENGLISH English units set will be used.

LENGTH=FT Units of length are feet.

TEMP=50 Temperature set to 50 units.

PRES=2.0E2 Pressure is 200 units.

VISC= Indicates that a single value of viscosity is required.

VISC=temp1,value1 /temp2,value2

Indicates that the program requires two data values with their associated temperatures

4-8 Input Reference

The input instructions explain which qualifiers are available for each keyword. Examples are:

Commenting Input

For clarity, you may add comments to your input. If a dollar sign ($) is placed in a statement, any text on that statement that appears after the $ is ignored. For example:

PRES(BAR)=3.54 $Field data, taken 2315 10/16/94

Default Data

Many of the data items required by PIPEPHASE have default values assigned to them. If you do not explicitly specify a value for an item of data, or select a calculation method, the program will automatically assign a value or method. For example, pipe thermal conductivity assumes a default value of 29 BTU/hr-ft-oF if you do not specify a value. Similarly, the Moody method for single-phase pressure drop calculations is chosen, by default, as it is generally suitable for many engineering purposes.

Beware, these default selections are not neccessarily the most appropriate, or best for your particular application. They do not substitute for engineering judgement. If an doubt, especially for the choice of a calculation method, consult chapter 4 of the manual for advice.

The input instructions indicate the defaults that the program will use in the absence of user input. All the numerical defaults in the input instructions are expressed in terms of the units of measurement of the English set.

When you specify a value or override a default in the General Data Category of input your value becomes the default for the entire simulation. You can then override your own default value later in the input. For example, to specify that all but one of your pipes are surrounded by air, you would have in the General Data Category of input:

DEFAULT AIR, VELOCITY=20

You would specify most of your pipes in this way:

PIPE ID=4, LENGTH=150

For the one pipe that is buried, the PIPE statement would look like this:

PIPE SOIL, ID=5, LENGTH=100, BDTOP(FT)=1

ID(IN)=12 Inside diameter is 12 inches.

PRES(BAR,ESTI)=2 Estimated pressure is 2 bars absolute.

POWER(MAX,KW)=17 Maximum power is 17 kilowatts.


Units of Measurement

Many items of data that you input to PIPEPHASE have a unit of measurement associated with them. Most have alternatives: for example, length can be measured in feet, meters, miles, or kilometers and temperature in oF, oC, oR, or K. It is possible to specify the unit of measurement individually for every item of data. However, to avoid having to do this, you may define the units that are to be used for each quantity – temperature, duty, power etc. – throughout the whole simulation input. This is done on the DIMENSION statement in the General Data Category of input. Individual data items may be expressed in different units by using qualifiers as described above.

For convenience, PIPEPHASE has four sets of units of measurement: Petroleum, English, Metric and SI. Each set has predefined units for each data item. You may select a set of units, globally override some of the predefined units and then override units for any individual data item. In this way, you have complete input flexibility.

For example, if you wanted to use the SI predefined unit set but with pipe length in feet and short length (e.g., for pipe diameter) in inches, your General Data Category of input would contain the statement:

DIMENSION SI, LENGTH=FT,IN

If the inside diameter of one of your pipes is measured in millimeters, you would have in the Structure Data Category of input:

PIPE ID(MM)=25.4

Basis of Measurements

With some quantities, for example flow and composition, you can also choose a basis of measurement. The basis may be molar weight, liquid volume, or gas volume and you may use a qualifier to define it. If you also specify a dimensional unit for the quantity, the unit must be appropriate to the basis. You cannot, for example, specify pounds per hour for a liquid volume flowrate. A valid example would be:

RATE(GV,CFM)=1.E-3

where the value specified, RATE keyword and the qualifiers GV and CFM combine to mean the gas volume rate has a value of 0.001 millions of standard cubic feet per minute.

The input instructions explain which bases are allowed. If a basis is specified but no unit of measurement is entered, PIPEPHASE will assume the unit to be the default appropriate to the basis which you defined.

Multiple Units of Measurement

Some input items, for example a curve of viscosity against temperature, have more than one unit of measurement. You can specify one or both units as qualifiers:

VISC(C,CP)=100,1.0/200,0.7

4-10 Input Reference

The order in which the qualifiers are entered is not important.

Continuing Statements

Input statements too long to fit on one line may be continued onto a second line or further by using an ampersand (&) or an asterisk (*) as a continuation character.

DIMENSION SI, LENGTH=FT, TEMP=C

is the same as

DIMENSION SI, LENGTH=FT, & TEMP=C

Layout of Input

You may indent any line of input to make the data more readable and you may have any number of spaces between data entries. For example:

DIMENSION SI, LENGTH=FT, & TEMP=C

is equivalent to

DIMENSION SI, LENGTH = FT, &\ TEMP= C

However, you may not embed blanks in your keywords or data entries.

Input Statement Descriptions

Legend

The data categories are described in this chapter. A full listing of statements with their associated keywords appears at the start of each data category. Each statement and keyword is then explained in detail. The following conventions apply:

BOLD Bold capitals are used for keywords. For example: ENGLISH You must use this word exactly as it is printed (or truncate it to four or more characters). A keyword with an equals sign (=) after it must be followed a value or another keyword.

UNDERLINE Default keywords are indicated by underlining. For example: PETROLEUM If you omit the entry or statement, the program will use this keyword as the default.

LIGHT Light capitals are used for values, methods and entries. For example: INPUT=FULL If you omit the keyword and entry, the program will use the default.

A number indicates a numerical default value. For example: LAMINAR=3000 If you omit the keyword and entry, the program will use this value as the default.


Input Statement Descriptions > Legend …

or Alternative entries are separated by the word or. For example: {PETROLEUM or ENGLISH}

You may select only one of the options contained within curly brackets {} and separated by the word or.

{ } Curly brackets indicate that a statement, keyword, or group of keywords is/are optional. For example: {VELOCITY=value} Your input is valid without this entry. A default is usually invoked if an entry is omitted.

( ) Ordinary parentheses indicate that qualifiers are allowed. For example: ID()= Unless otherwise noted, qualifiers are units of measurement.

{} entries are optional () keyword qualifiers underlined keywords are defaults= requires values or entries values or entries for keywords are defaults in Petroleum units


GENERAL Data Category of Input

Global Parameters

The GENERAL Data Category of Input defines global parameters that control the whole flowsheet.

Table 4-2: GENERAL Data Category of Input

Statement Keywords See page...

TITLE {PROJECT=}, {PROBLEM=}, {USER=}, {DATE=}, {SITE=}

p. 14

{DESCRIPTION} any text p. 14

{DIMENSION} {PETROLEUM or ENGLISH or METRIC or SI}, {VELOCITY=, TEMPERATURE=, PRESSURE=, LENGTH=, VISCOSITY=, DUTY=, POWER=, DENSITY= or GRAVITY=, RATE(M)=, RATE(W)=, RATE(LV)=, RATE(GV)=}

p. 14

CALCULATION NETWORK or SINGLE or GASLIFT or PVTGEN or PVTRUN or PVTTAB, BLACKOIL or CONDENSATE or LIQUID or GAS or STEAM or COMPOSITIONAL(), {SPHERING, ISOTHERMAL, NOACCEL, NORUN, PRANDTL}, MASS

p. 20

{FCODE} {PIPE=BBM or MOODY, ANNULUS=BBM or MOODY, TUBING=BBM or MOODY, PALMER=0.924,0.685, LAMINAR=3000}

p. 21

{DEFAULT} {WATER or AIR or SOIL, VELOCITY()=, TAMBIENT()=80, TGRADIENT()=1.0, DENSITY()=, VISCOSITY()=, CONDUCTIVITY()=,UPIPE()=1.0, UANNULUS()=1.0, UTUBING()=1.0, HINSIDE()=0.0, HOUTSIDE()=0.0, HRADIANT()=0.0, BDTOP=0, THKPIPE()=0.3125, THKINS()=0, CONPIPE()= 29, CONINS()=0.015, CONSOIL()=0.8, IDPIPE()= or NOMD=, NOMR=, NOMT=, PIPSCHEDULE=DIAMDATA.DAT, SCHEDULE=40, SCHR=40, SCHT=40, IDANNULUS()=, IDTUBING()=, ODTUBING()=, FLOWEFF=, ROUGHNESS()=0.0018, HWCOEFF()=150,}

p. 24

{SEGMENT} {DLHORIZ()=, or NHORIZ=1, DLVERT()=, or NVERT=1, MAXSEGS=20, DTIME=10, AUTO=ON, FAST, PSEG=20, TSEG=5, PTOL=0.2, HTOL=0.05, ITER=25

p. 26

{LIMITS} {TEMPERATURE(MIN)=-60, TEMPERATURE(MAX)=800, PRESSURE(MIN)=0.0, PRESSURE(MAX)=25000}

p. 28

{PRINT} {INPUT=FULL,DEVICE=SUMMARY, PROPERTY=NONE, CONNECT=FULL, FLASH=FULL, SUMMARY=BOTH, DATABASE=NONE, PLOT=NONE, MAP=NONE, ITER, SLUG=BRILL}, SIMULATOR= PART or FULL, OPTIMIZER=PART or FULL, MERGESUB, NODACT

p. 28


GENERAL Data Category of Input > TITLE …

TITLE

Mandatory statement. Introduces the general category.

Optional entries:

Example:TITLE PROJ=TEST1, PROB=FEED, USER=TECH DEPT, DATE=7/5/94

DESCRIPTION

Optional statement. Allows you to enter a description of the simulation. You can have up to four DESCRIPTION statements. The information on these statements is printed once at the start of the output page.

Mandatory entries: NoneOptional entries:

Example:DESC THIS SIMULATION IS A GASLIFT OPTIMIZATION STUDY ONDESC WELL #321s

DIMENSION

Optional statement. Defines the units of measurement for each data item in the input. Select a set of units and/or override individual units. If you omit this statement, units will default to those in the ENGLISH set. Table 4-3 and Table 4-4 define the Primary and Secondary Units of Measurement in each standard set and other permitted units that can be used with this statement. You can also use these units for specific data items by using qualifiers.

Mandatory entries: None

{OUTDIMENSION} {ADD or REPLACE, PETROLEUM or ENGLISH or METRIC or SI, VELOCITY=, TEMPERATURE=, PRESSURE=, LENGTH=, VISCOSITY=, DUTY=, POWER=, DENSITY= or GRAVITY=, RATE(M)=, RATE(W)=, RATE(LV)=, RATE(GV)=}

p. 31

PROJECT=PROBLEM= USER= DATE= SITE=

Use any or all of these entries for administrative information. PROJECT, PROBLEM, USER and DATE entries appear on every page of output. The SITE keyword is used for accounting in multi-site installations. Each entry can have up to 12 alphanumeric characters. The DATE entry can include the / character.

DESCRIPTION Up to four lines of text each containing up to 60 characters of text.

Table 4-2: GENERAL Data Category of Input (cont.)




Optional entries:

Example:DIME SI, LENGTH=KM,IN, VISC=CP, DENS=SPGR, RATE(GV)=CF

ENGLISH or PETROLEUM or METRIC or SI

Select only one of these sets of units.

VELOCITY= TEMPERATURE=PRESSURE= LENGTH= VISCOSITY= DUTY= POWER= DENSITY= or GRAVITY=

Define the units in which you want to specify any or all of these quantities. LENGTH has two arguments: the first is long length, for pipe lengths, pipe elevations, etc.; the second is short length for diameters, roughness, etc.

RATE(M)= RATE(W)= RATE(LV)= RATE(GV)=

Define the units in which you want to specify any or all of molar, weight, liquid volumetric and gas volumetric flowrates. Gas Volumetric rate is always expressed in millions of units. Thus CFD means millions of cubic feet of gas per day.

Table 4-3: Primary Units of Measurement

Petroleum English Metric SI Other Permitted Units

AREA FT2 FT2 M2 M2 CM2, MI2, ACRE, KM2, IN2

DENSITY or GRAVITY1 (liq.)

API API KGM3 KGM3 SPGR, LBFT3

DENSITY or GRAVITY1 (gas)

SPGR SPGR KGM3 KGM3 LBFT3

DUTY BTUHR BTUHR KCHR KW KJHR

LENGTH FT, IN FT, IN M, MM M, MM CM, KM, MI

POWER HP HP KW KW

PRESSURE PSIG PSIA BAR KPA PSF, ATM, ATA, PA, KGCM, ATE

RATE(GV)3 CFD CFHR CMHR CMHR CFS, CFM, CMD

RATE(LV) BPD CFHR CMHR CMHR CFS, CFM, CFD, CMD, LHR, BPH, GPM

RATE(M)2 MOLHR MOLHR MOLHR MOLHR MOLD

RATE(W) LBHR LBHR KGHR KGHR LBD, MLBHR, MLBD, KGD, THRM, TDM

ROUGHNESS4 IN IN MM MM CM, FT

TEMPERATURE F F C K R

VELOCITY MPH FPS KMPH MPS

VISCOSITY CP CP CP PAS KGMHR, LBFTHR, CST, SSU, M2HR, FT2HR


GENERAL Data Category of Input > DIMENSION …

Table 4-4: Secondary Units of Measurement

1 When DENSITY or GRAVITY is API, gas density is specific gravity with respect to air at 60oF and 1 atmosphere.

2 Molar rates are lb-moles for Petroleum and English unit sets, kg-moles for Metric and Si unit sets. 3 Units of measure for RATE(GV) are always in millions of units.4 The default units for ROUGHNESS will change (to obey relative consistency and meaning) if the unit for short

length is modified by the user, as per the following rules:• If the global dimension set is ENGLISH or PETROLEUM, and the short length unit is overridden to

become MI (miles), then the ROUGHNESS unit increases from IN (inches, default) to FT (feet).• If the global dimension set is ENGLISH or PETROLEUM, and the short length unit is overridden to

become M (meters) or KM (kilometers), then the ROUGHNESS unit decreases from IN (inches, default) to CM (centimeters).

• If the global dimension set is METRIC or SI, and the short length unit is overridden to become M (meters) or KM (kilometers), then the ROUGHNESS unit increases from MM (millimeters, default) to CM (centimeters).

• If the global dimension set is METRIC or SI, and the short length unit is overridden to become MI (miles), then the ROUGHNESS unit increases from MM (millimeters, default) to FT (feet).

5 The volume can be defined using the keyword VOLUME. The units of measure are BBL for Petroleum unit set, FT3 for English unit set, M3 for Metric and SI unit sets.

Petroleum English Metric SI Other permitted units

Angle DEG DEG DEG DEG RAD

Condensate Gas Ratio

BBLMMSCF BBLMMSCF

M3MM3 M3MM3

Gas Oil Ratio CFTBBL CFTBBL M3M3 M3M3 CFTCFT

Heat Transfer Coeff BTUFTF BTUFTF KCMC WMC BTUINF, CALCMC, KJMC

Fetkovich IPR COEFFICIENT

MCFD MCFD M3HB M3HK

Perforation Density FT FT M M

Permeability D D D D MD

Roughness* IN IN MM MM CM, FT

Solution Gas Oil Ratio

CFTBBL CFTBBL M3M3 M3M3 CFTCFT

Specific Heat BTULBF BTULBF KCKGC KJKGC

Temperature Gradient

F100FT F100FT C100M C100M CKM

Thermal Conductivity

BTUFTF BTUFTF KCMC WMC BTUINF, CALCMC, KJMC

Thermal Expansion F F C C K, R

Water Gas Ratio BBLMMSCF BBLMMSCF

M3MM3 M3MM3

* The default unit for ROUGHNESS changes (to obey relative consistency and meaning) if you modify the unit for short length. If the short length unit is entered as MI (miles), the default roughness unit is FT (feet). If the short length unit is entered as M (meters) or KM (kilometers), the default roughness unit is CM (centimeters).

Table 4-3: Primary Units of Measurement (cont.)

Petroleum English Metric SI Other Permitted Units



Table 4-5: Keywords Used to Define UOMs

UOM Description

ACRE Acre

API API gravity

ATA technical atm abs

ATE technical atm gauge

ATM atmospheres

BAR bars absolute

BBLMMSCF barrels/million ft3

BPD barrels/day

BPDPSI barrels/day/psi

BPH barrels per hr

BTUFT2F BTU/hr-ft2-°F

BTUFTF BTU/hr-ft-°F

BTUHR millions BTU/hr

BTULBF BTU/lb-°F

C* degrees Celsius

C** per degree C

C100M °C/100 meters

CFD ft3/day for liquid volumes, million ft3/day for gas volumes

CFHR ft3/hr for liquid volumes, million ft3/hr for gas volumes

CFM ft3/minute for liquid volumes, million ft3/minute for gas volumes

CFS ft3/second for liquid volumes, million ft3/sec for gas volumes

CFTBBL ft3/barrel

CFTCFT ft3/ft3

CKM °C/kilometer

CM centimeters

CMD m3/day for liquid volumes, million m3/day for gas volumes

CMHR m3/hr for liquid volumes, million m3/day for gas volumes

CP centipoise

CST centistoke

D Darcy

DEG degrees

F* degrees Fahrenheit

F** per degree F

F100FT °F/100 ft

FPS ft/second

FT* feet

FT** number/ft

FT2HR ft2/hr

* Primary UOM ** Secondary UOM


GENERAL Data Category of Input > DIMENSION …

GPM US gals/minute

HP horsepower

HR hours

IN inches

IN2 sq inches

K* Kelvin

K** per degree K

KCHR million kcals/hr

KCKGC kcals/kg-°C

KCMC kcals/m2-hr-°C

KCMC kcals/m-hr-°C

KGCM kg/cm2

KGD kg/day

KGHR kg/hr

KGM3 kg/m3

KGMHR kg/m-hour

KJHR million kJ/hr

KJKGC kJ/kg-°C

KM kilometers

KM2 sq kilometers

KMPH km/hr

KPA kilopascals

KW kilowatts (power)

KW million kw (duty)

LBD lb/day

LBFT3 lb/ft3

LBFTHR lb/ft-hr

LBHR lb/hr

LHR liters/hr

M* meters

M** number/meter

M2HR sq meters/hr

M3DBAR m3/day/bar

M3HB million m3/hr-bar2n

M3HK million m3/hr/k3Pa2n

Table 4-5: Keywords Used to Define UOMs (cont.)

UOM Description




M3HRBAR m3/hr-bar

M3M3 m3/m3

M3MM3 m3/million m3

MCFD 106 ft3/day-psia2n (for Fetkovich Coefficient), 103 ft3/day (for gas volume rate)

MD millidarcy

MFT3DPSI thousand ft3/day-psi

MI miles

MI2 sq miles

MIN minutes

MKGHRBAR thousand kg/hr-bar

MLBD thousand lb/day

MLBHR thousand lb/hr

MLBHRPSI thousand lb/hr-psi

MM millimeters

MM2 sq millimeters

MOLD moles/day

MOLHR moles/hr

MPH miles/hr

MPS meters/second

PA Pascals

PAS Pascal-seconds

PSF lb/ft2

PSIA lb/in2 absolute

PSIG lb/in2 gauge

R* degrees Rankine

R** per degree R

RAD radians

SPGR specific gravity

SSU SSU viscosity

TDM metric tonnes/day

THRM metric tonnes/hr

WMC watts/m-°C

WMC watts/m2-°C

Table 4-5: Keywords Used to Define UOMs (cont.)

UOM Description



GENERAL Data Category of Input > CALCULATION …

CALCULATION

Mandatory statement. Specifies the type of calculation, the fluid type, the options for the decision variables, constraints, specifications, and objective function, as well as general optimization parameters.

Mandatory entries:

Optional entries:

NETWORK or PVTGENGASLIFT

Select only one of these to invoke the calculation method. Select PVTGEN if you want to generate PVT fluid property tables for use in a subsequent run (See also the PVT Category of Input). You can use PVTGEN with BLACKOIL and COMPOSITIONAL fluids only. Select NETWORK to solve basic network simulations. Select SINGLE to focus in on a single link or for nodal analysis. Select GASLIFT to use the gaslift analysis package.

Note: The GUI will automatically select the SINGLE algorithm when required for line sizing and nodal analysis calculations.

PVTRUN or PVTTAB

Generate PVT tables and run a simulation using these tables. The simulation uses compositional PVT tables as specified in the PVTFILE SETNO. Phase envelope and hydrate predictions will not be performed using this option.

BLACKOIL or CONDENSATE or LIQUID or GAS or STEAM or COMPOSITIONAL()

Select only one of these to describe the fluid type. BLACKOIL, CONDENSATE, LIQUID, GAS and STEAM are non-compositional fluids. You can define their properties in the PVT Data Category of input. Use COMPOSITIONAL if you want to define the fluid as a mixture of components or petroleum fractions (entered either directly or indirectly via a distillation curve). Use the qualifier GAS or LIQ or BLACK to specify that a compositional fluid is only gas or only liquid or only mixed compositional blackoil models, therefore bypassing any two-phase flash calculations.

SPHERING Use this keyword to invoke sphering or pigging calculations. Note that a sphering report will be generated only if you specify DEVICE=PART, or greater, in the print options.

ISOTHERMAL Suppress heat balances on all flow devices. You can override this on individual flow devices. Not available with COMPOSITIONAL() fluids or STEAM.

NOACCEL Ignore the acceleration term in pressure drop calculations.

NORUN Suppress calculations perform input checks only.

PRANDTL Invokes a rigorous Prandtl number calculation for inside and outside film heat transfer coefficients. If you omit this keyword, a Prandtl number of 1.0 will be used.

MASS Converts standard mass based volume formulation to mass based formulation. This option is needed when modeling separators and flow splitting at junctions.



Example:CALC NETWORK, COMPOSITIONAL(GAS) $to specify a network comp. gas runCALC NETWORK, COMPOSITIONAL(BLACK) $to specify a network comp. blackoil run

FCODE

Optional statement. Selects pressure drop and hold-up correlations. If you omit this statement, PIPEPHASE will use MOODY for non-compositional liquid or gas or BBM for any other fluid.


Example:FCODE PIPE=BBM, PALMER=0.9,0.7, TUBING=HB, PALMER=1.0, 0.

PIPE=ANNULUS= TUBING=

Define the correlation to be used for pressure drop calculations in pipes, annuli, and tubings. See Table 4-6a and Table 4-7 for available methods. Default is BBM for compositional, blackoil, condensate and steam fluids and MOODY for non-compositional liquids and gases.

PALMER=0.924,0.685 Specify global Palmer liquid holdup correction factors. Different global Palmer data may be input for pipes, annuli, and tubings. These global data may be over-ridden on individual flow devices.

The PALMER keyword must follow immediately after the PIPE, ANNULUS, or TUBING to which the Palmer data is to be applied. The first number is applied to uphill flow holdup correction and the second is applied to downhill flow.

Two values must be supplied: uphill and downhill. The defaults shown apply only to BB or BBM correlations. If you want to use the defaults, enter only the PALMER keyword without any values. If different values are required, supply those values with the PALMER keyword. If you are using a correlation other than BB or BBM, you must supply values with the PALMER keyword. If you need to correct only for downhill holdup, supply a value of 1.0 for the uphill correction factor.

LAMINAR=3000’ Define the value of the Reynolds number to be used as the boundary between laminar and turbulent flow.


GENERAL Data Category of Input > FCODE …

Table 4-6a: Pressure Drop & Hold-Up Methods for Compositional, Blackoil, Condensate and Steam

Table 4-6b: Methods in Table 4-6a for Vertical or Near Vertical Upward Flow

Method Keyword Application

Beggs & Brill BB Pipe Tubing Annulus

Beggs & Brill - Moody BBM Pipe Tubing Annulus

Beggs & Brill - No slip BBNS Pipe Tubing Annulus

Beggs & Brill - Moody-Eaton BBME Pipe Tubing Annulus

Beggs & Brill - Moody-Dukler BBMD Pipe Tubing Annulus

Beggs & Brill - Moody-Hagedorn & Brown

BBMHB Pipe Tubing Annulus

Beggs & Brill high velocity BBHV Pipe Tubing Annulus

Beggs & Brill - Moody high velocity BMHV Pipe Tubing Annulus

Beggs & Brill - No slip high velocity BBNH Pipe Tubing Annulus

Mukherjee & Brill MB Pipe Tubing Annulus

Mukherjee & Brill-Eaton MBE Pipe Tubing Annulus

TACITE-STM,1 TACS Pipe Tubing Annulus

OLGA-S2 OLGA Pipe Tubing Annulus

1, 2, 3 See footnotes to Table 4-6c.


Ansari ANSA Pipe Tubing Annulus

Orkiszewski ORK Tubing Annulus

Duns & Ross DR Tubing Annulus

Hagedorn & Brown HB Tubing Annulus

Hagedorn & Brown - Beggs & Brill HBBB Tubing Annulus

Aziz AZIZ Tubing Annulus

Gray (not applicable for compositional)

GRAY Tubing Annulus

Gray - Moody (not applicable for compositional)

GRYM Tubing Annulus

Angel - Welchon - Ross ANGEL Tubing Annulus

1, 2, 3 See footnotes to Table 4-6c.



Table 4-6c: Methods in Table 4-6a for Horizontal or Near Horizontal Flow

Table 4-7: Single-Phase Pressure Drop Methods


Xiao XIAO Pipe

Eaton EATON Pipe

Eaton-Flanigan* EF Pipe

Dukler DUKLER Pipe

Dukler-Flanigan* DF Pipe

Lockhart & Martinelli LM Pipe

Dukler-Eaton-Flanigan* DE Pipe

Olimens OLIM Pipe

User Defined Method UDP1 Pipe Tubing Annulus

User Defined Method UDP2 Pipe Tubing Annulus

1 The TACITE-S mechanistic method is developed and maintained by the French companies IFP, Total and Elf Aquitaine Production, and is available only under a separate license agreement with SimSci. Please consult your local SimSci representative for details.

2 The OLGA-S mechanistic method is available under separate license agreement with SimSci. Please consult your SimSci representative for details.

3 Also allowed for the compositional gas option.* Flanigan holdup connection for downward inclined pipes

Method Fluid Keyword Application

Moody3 Liquid or Gas

MOODY Pipe Tubing Annulus

Hazen-Williams Liquid HW Pipe Tubing Annulus

Panhandle B3 Gas PANB Pipe Tubing Annulus

Weymouth3 Gas WEYM Pipe Tubing Annulus

American Gas Association3

Gas AGA Pipe Tubing Annulus

TACITE-S1 TACS Pipe Tubing Annulus

OLGA-S2 OLGA Pipe Tubing Annulus

User-Defined Method Liquid or Gas

UDP1 Pipe Tubing Annulus

User-Defined Method Liquid or Gas

UDP2 Pipe Tubing Annulus

1, 2, 3 See footnotes to Table 4-6c..


GENERAL Data Category of Input > DEFAULT …

DEFAULT

Optional statement. Sets up global values to be used throughout the simulation. All these can be overridden selectively on the flow device and fitting statements in the STRUCTURE Data Category of input.


WATER or AIR or SOIL

Use one of these to specify the medium surrounding the pipes. If no surrounding is chosen, the default heat transfer coefficient for the pipe is used. If more than one surrounding is entered, then without any overriding information supplied on the PIPE statement in the Structure Data Category of input, the hierarchy of usage is given by: SOIL has default preference over WATER which has default preference over AIR

Therefore, if all three surroundings are defined on this statement, they will be prioritized per the above logic.

More than one surrounding may be specified on this statement. In this case the input order of the attributes of the surroundings (such as velocity) must logically follow the surrounding medium these attributes refer to (see the second example at the end of this section).

If any of the following keywords are entered and no surrounding is input, the surrounding defaults to SOIL:

VISCOSITY VELOCITY DENSITY BDTOP THKPIPE THKINS CONPIPE CONINS CONSOILCONDUCTIVITY

HAUSEN Specifying this keyword activates a special inside film coefficient calculation (Hausen) when laminar heat transfer flow conditions exist (valid for Re < 2000). If this keyword is not specified, the normal turbulent flow calculation is used for all conditions of flow.

VELOCITY()= Velocity of the surrounding air or water. Default values are 10 miles/hr for air and 1 mile/hr for water.

TAMBIENT()=80 Ambient temperature of the surrounding medium.

TGRADIENT()=1.0 Geothermal temperature gradient.

DENSITY()= Density of the surrounding air or water. Defaults are specific gravity of 1.0 for air and 10.0 API for water.

VISCOSITY()= Viscosity of the surrounding air or water. Defaults are 0.02 cP for air and 1.0 cP for water.

CONDUCTIVITY()= Thermal conductivity of the surrounding air, soil, or water. Defaults are 0.015 BTU/hr-ft-F for air, 0.8 BTU/hr-ft-F for soil and 0.3 BTU/hr-ft-F for water.

UPIPE()=1.0 If no medium is invoked directly or indirectly, this overall heat transfer coefficient will be used.



UANNULUS()=1.0UTUBING()=1.0

Overall heat transfer coefficient from inside an annulus or tubing to the surroundings.

HINSIDE()=0.0 Additional heat transfer resistance which will be added to the inside film heat transfer resistance calculated by PIPEPHASE.

HOUTSIDE()=0.0 Additional heat transfer resistance which will be added to the outside film heat transfer resistance calculated by PIPEPHASE.

HRADIANT()=0.0 Additional radiant heat transfer resistance which will be added to the outside film heat transfer resistance calculated by PIPEPHASE.

BDTOP()=0 Depth of a buried pipe measured from the top of the outside of the pipe, in short length units. A positive value must be supplied when SOIL has been selected as the surrounding.

THKPIPE()=0.3125 Pipe thickness in short length units.

THKINS()=0 Insulation thickness in short length units. Maximum of 5 values.

CONPIPE()=29 CONINS()=0.015 CONSOIL()=0.8

Thermal conductivity of the pipe material, insulation (maximum of five values, for five insulation layers) and soil.

IDPIPE()= or NOMD=

Inside diameter of pipes and fittings in short length units. Nominal inside diameter of pipes and fittings, in inches only.

NOMT= Nominal inside diameter of tubing devices, in inches only.

PIPSCHEDULE= DIAMDATA.DAT

Name of external text file in the user directory containing pipe and tubing schedule data which are to be invoked for all nominal size specifications. If a file name is supplied, the input file extension must be .DAT. The PIPSCHEDULE keyword may or may not be included in this statement. If this keyword is omitted, then an internal table is used with default values.

Note: If a nominal diameter is not available for a user-defined schedule in the selected table or file, the next smaller schedule is searched.

SCHEDULE=40 Default pipe schedule to be used for fittings, pipe and line sizing options.

SCHT=TB01 Default schedule for tubing devices.

DESC= Twenty-character description of type of pipe used.

Note: If a nominal diameter is not available for a user-defined schedule in the selected table, PIPEPHASE will generate an error message. If a schedule is not defined, the default schedule 40 is used and, if a match cannot be found, PIPEPHASE will produce an error message.

IDANNULUS()= Inside diameter of annulus in short length units.

IDTUBING()= Inside diameter of tubing in short length units.

ODTUBING()= Outside diameter of tubing in short length units.

FLOWEFF=100 Flow efficiency as a percentage. This parameter may be used in a rating exercise to adjust flowrates to meet a measured pressure drop. The use of FLOWEFF is recommended only when other parameters, such as pressure drop method, pipe roughness, heat transfer coefficient values, etc., have been varied in order to match field data.

ROUGHNESS()=0.0018 Pipe inside roughness. Use the qualifier REL to denote roughness as a fraction of the pipe inside diameter. Otherwise, value is absolute and in short length units.


GENERAL Data Category of Input > SEGMENT …

Example:DEFAULT AIR, TAMB=40, VELOCITY=30, THKINS=4DEFAULT AIR, COND=0.01, VISC=0.018, VELOCITY=8, WATER,& COND=0.34, VELOCITY=5

SEGMENT

Optional statement. Controls the segmenting of pipes, annuli, and tubing for pressure drop and heat transfer calculations. If you omit this statement, PIPEPHASE will use a default of one segment per pipe, annulus, and tubing.


HWCOEFF()=150 Coefficient for Hazen-Williams pressure drop method.

DLHORIZ()= or NHORIZ=1

Length of a pipe calculation segment in long length units. Number of calculation segments per pipe.

DLVERT()= or NVERT=1

Length of an annulus or tubing calculation segment in long length units. Number of calculation segments per annulus or tubing.

MAXSEGS=20 Maximum number of calculation segments per flow device. This overrides any value calculated from other data on this statement.

DTIME=10 Time step for pigging or sphering in seconds.

PSEG=20 This option only applies when the AUTO or FAST segmentation options are used. When this keyword is invoked and either AUTO or FAST are specified, PIPEPHASE will automatically size segments so that the maximum average pressure drop per segment is PSEG or no more than MAXS segments are used in a pipe/tube/annulus. By default, a value of 20 psia is used for PSEG.

TSEG=5 This keyword is activated with the use of the AUTO or FAST keywords (described below). Under this option, PIPEPHASE attempts to insure that the temperature drop across a segment is TSEG and the absolute pressure drop is PSEG and the maximum number of segments is MAXS. PIPEPHASE uses a default value of 5 F for TSEG.

PTOL=0.2 The pressure traverse algorithm uses for property computations, the pressure and temperature at the mid-point of each segment. Because mid-point values are used, the algorithm must use an iterative procedure to converge to a mid-point pressure. PTOL is the convergence criterion for the mid-point pressure and is 0.2 psia by default (Minimum tolerance = 0.0001 psia).

HTOL=0.05 This is option only applies to compositional or steam systems and it refers to the convergence tolerance that is to be used for segment mid-point enthalpies. By default, HTOL is equal to 0.05 Btu/lb.



Example: SEGM DLHOR=50, MAXSEGS=10

Note: When using horizontal tubing devices, the user should use a set number of segments rather than a vertical segmentation specification. With no vertical depth specified, the device will default to a few segments regardless of the length. The user should specify a number of segments allow for better property predictions along the horizontal well.

ITER=25 This refers to the number of iterations that are to be used to compute the mid-point pressure/temperature in a given segment. By default, ITER is set to 25. When ITER=1, the traverse algorithm reduces to the forward Euler integration procedure. The forward Euler is, in principle, faster than the mid-point weighting used by default in PIPEPHASE. However, it also leads to less accurate traverses than are produced by the mid-point weighting method.

AUTO=ON When invoked, this option automatically sizes segments according to computed pressure and temperature gradients. The following options (discussed above) are invoked with this keyword:PSEG = 20 psiaTSEG = 5 F PTOL = 0.2 psiaHTOL = 0.05 Btu/lb ITER = 25MAXS= 50

AUTO=OFF Allows the user to specify the flow device segment length, either directly, or through a user-specified number of segments. By default, this option is set to Manual Segmentation Method. The following defaults are invoked by this keyword:DLHORIZ=2000 feetDLVERT=500 feetNHOR=1NVER=1MAXSTEPS=20

FAST When invoked, this option uses an automated, yet more relaxed than AUTO, segmenting procedure to estimate the size of segments. The following defaults are invoked by this keyword:PSEG = 50 psia TSEG = 50 FPTOL = 0.2 psia HTOL = 1 Btu/lb ITER = 1 (thus the traverse algorithm reduces to the forward Euler method) MAXS = 20

Under the FAST keyword, PIPEPHASE will compute pressure traverses at a faster rate than under the AUTO option. However, because of the coarser segmentation and the use of forward Euler marching, the pressure traverse estimates are expected to be less accurate than under default segmentation procedures.

Note: Under the FAST and AUTO options, the user has complete control of the segmentation options PSEG, TSEG, PTOL, HTOL, ITER and MAXS


GENERAL Data Category of Input > LIMITS …

LIMITS

Optional statement. Set the minimum and maximum temperatures and pressures for calculations. If calculations stray outside these limits, PIPEPHASE will print a warning message. You should ensure that the pressure and temperature limits correctly bound their anticipated values in the simulation prior to program execution. The default limits are those judged to be representative for all of the thermodynamic methods available to PIPEPHASE.

If the simulation conditions are over a narrower range of conditions than the default values, you still should not reduce the range for the limits. Reducing the range can make it more difficult for the network to solve by giving poor PVT predictions during intermediate calculations.


Example: LIMITS PRES(MIN)=5

PRINT

Optional statement. Controls the level of output produced by PIPEPHASE.


TEMPERATURE(MIN)=-60TEMPERATURE(MAX)=800PRESSURE(MIN)=0PRESSURE(MAX)=25000

Minimum and maximum temperatures and pressures. Additional qualifiers may be used to specify units of measurement.

INPUT=FULLSUMMARY=BOTHDEVICE=SUMMARY PROPERTY=NONE or SUMMARY or PART or FULLCONNECT=FULL FLASH=FULLPLOT=FULL

Select an option for each of these from Table 4-8, Options for Output. CONNECT applies only to networks. FLASH applies only to compositional fluid types. The PLOT and MAP options can only be invoked with DEVICE=PART or DEVICE=FULL.

MAP=TAITEL or NONE Use MAP=TAITEL to print the Taitel-Dukler-Barnea flow regime map for each link. DEVICE=PART or DEVICE=FULL must also be specified



Example:PRINT INPUT=NONE, PROPERTY=FULL, DATABASE=FULL

Table 4-8: Options for Output

MERGESUB Independent subnetworks are formed, when specifying the upstream pressure or flow rate to a choke/regulator or inlet pressure to a Multi-Stage Compressor. Pseudo nodes and links are created for the boundaries of these individual networks. Invoke this option to merge these nodes and links back to its original network before generating the output report.

NODACT Use this to report node summary at actual conditions. If ignored, node summary is reported at standard conditions.

SLUG=BRILL Invokes a statistical slug model. The options are BRILL, NORRIS or SCOTT. Only with DEVICE=PART or DEVICE=FULL for single links only.

ITER Request detailed printout during the convergence of an iterative network calculation.

SIMULATOR=PART Choose to print the network simulation results for every cycle, SIMULATOR=FULL, or at the final cycle, SIMULATOR=PART.

OPTIMIZER=PART Choose to print the optimization results after every iteration, OPTIMIZER=FULL, or at the end of the simulation, OPTIMIZER=PART.

VFPT = DEFAULT EXCEL, ECLIPSE,GCOM(hidden), USER. EXCEL is default; generates VFP tables.

DATABASE=FULL Controls the writing of data to a database after solution for use with the Results Access System through the GUI. Options are FULL, LAST, and NONE. FULL writes all data from all cases to the database; LAST writes only data from the last case; NONE writes no data.

Entries

Keyword NONE SUMMARY PART FULL

INPUT List of input No details

N/A List of inputStructure details

List of input Full details

DEVICE No device details or summary

Device summary

Summary report plus pressure, temperature, liquid holdup and velocities

All PART reports plus pressure gradient reports

PROPERTY No reports N/A Point by point physical property data

Prints all point by point physical property data plus heat transfer data and hydrate prediction

CONNECT No reports N/A N/A Tables and plot of network connectivity

FLASH No reports N/A N/A Composition and phase properties at each node


GENERAL Data Category of Input > PRINT …

PLOT No plots N/A Link pressure and temperature plots. DEVICE=PART or DEVICE=FULL must also be specified.

Link pressure, temperature and phase envelope plots. DEVICE=PART or DEVICE=FULL must also be specified

DATABASE No file produced for Results Access System

N/A Only last CASE STUDY produced in Results Access System file

All output data produced in Results Access System file

OLD NEW BOTH

SUMMARY Node, Link and Device Summaries are produced.

Structure Data, Velocity and Results Summaries are produced.

Both the OLD and NEW set of reports are produced

Entries

Keyword NONE SUMMARY PART FULL



OUTDIMENSION

Optional statement. The normal output is produced in the same units of measurement as those defined in the DIMENSION statement. The OUTDIMENSION statement requests a second set of output and defines the units of measurement for it. Select a predefined set of units and/or override individual units. See Table 4-3, Primary Units of Measurement, and Table 4-4, Secondary Units of Measurement, for the definition of units in each predefined set and other units which can be specified for each data item. If this statement is omitted, a second set of output will not be generated.


Example:OUTDIME METRIC, VISC=PAS, DENS=API, RATE(M)=LBHR

ADD or REPLACE

Use one of these options to specify whether the second output should be added to the first output or should replace it.

PETROLEUM or ENGLISH or METRIC or SI

Select only one of these sets of units.

VELOCITY= TEMPERATURE=PRESSURE= LENGTH= VISCOSITY= DUTY= POWER= DENSITY= or GRAVITY=

Define the units in which any or all of these quantities are to be printed out.

RATE(M)= RATE(W)= RATE(LV)= RATE(GV)=

Define the units in which any or all of molar, weight, liquid volumetric and gas volumetric flowrates are to be printed out.


COMPONENT Data Category of Input > Overview …

COMPONENT Data Category of Input

Overview

The Component Data Section defines the components in a compositional simulation. This section is mandatory for a compositional fluid unless you are defining your fluid in terms only of an assay curve with no Lightends and you do not want to alter the default cuts or characterization criteria. This section is also mandatory for a mixed compositional/non-compositional blackoil model. This section must not be present if your fluid is non-compositional.

Chapter 1, SimSci Component Data Input Reference, in the optional SimSci Component and Thermodynamic Data Input Manual, describes all the features of the SimSci Component Data system. Many of these features are not used in PIPEPHASE because they are not relevant to pressure drop through pipes and fittings.

Of those that are relevant, the commonly used ones are described here in detail. The rest are summarized and you should refer to Chapter 1 of the SimSci Component and Thermodynamic Data Input Manual for input details.

Table 4-9a: COMPONENT Data Category for Input


COMPONENT None

LIBID number, name {, , alias}/ ..., BANK=, {FILL=} p. 34

{PETROLEUM()} number, name, mol wt, gravity, normal boiling point/... p. 34

{ASSAY} CHARACTERIZE= CAVETT, MW=CAV80, CONVERSION=API94, CURVEFIT=VER6 GRAVITY=WATSONK, {FIT=SPLINE, TBPIP=1, TBPEP=98, NBP=}

p. 35

{CUTPOINTS} TBPCUTS() = 100,800,28/1200,8/1600,4 p. 37

{Constants} MW SPGR API ACENTRIC ZC TC() PC() VC() NBP() STDDENSITY()

component number, value/...p. 37p. 37p. 37p. 37p. 37p. 37p. 37p. 37p. 37p. 37



Table 4-9b: Other Statements to Table 4-9a

COMPONENT

Mandatory statement for compositional fluids. Introduces the category.


{Variables} VP() ENTHALPY() CP() LATENT() DENSITY() VISCOSITY() CONDUCTIVITY() SURFACE

CORR = , {LN or LOG or EXPFAC = }, DATA = or TABULAR = p. 38

p. 38p. 38p. 38p. 38p. 38p. 38p. 38

Other statements For details, refer to Chapter 1, SimSci Component Data Input Reference, of the SimSci Component and Thermodynamic Data Input Manual.

NONLIBRARY Components that are not in the SimSci bank and for which you have to supply a full set of properties.

PHASE Identifies solid components

SYNCOMP Data for a synfuel component of a specific type.

SYNLIQ Data for a synfuel component that is a mixture of different petroleum types.

RACKETT Rackett parameter required for the Rackett method for liquid densities.

DIPOLE Dipole moment required for the Hayden-O’Connell method for vapor properties.

RADIUS Radius of gyration required for the Hayden-O’Connell method for vapor properties.

SOLUPARA Hildebrand solubility parameter required for various generalized and liquid activity thermodynamic correlations.

MOLVOL Liquid molar volume required for various generalized and liquid activity thermodynamic correlations.

VANDERWAAL Van der Waals area and volume required for UNIFAC and UNIQUAC liquid activity thermodynamic correlations.

STRUCTURE, GROUP Data for non-library components for use with the UNIFAC thermodynamic method.



COMPONENT Data Category of Input > LIBID …

LIBID

Optional statement. Identifies the components whose properties are to be taken from the SimSci databank.

Mandatory entries:

Example:LIBID 1, C1/2, C2/3, C3, BANK=SIMSCI, PROCESS LIBID 1, C1, METHANE/3, C3/2, ETHN, PURE ETHANE, * BANK=SIMSCI, PROCESS

PETROLEUM

Optional statement. Defines petroleum fraction pseudocomponents. Component properties are calculated using the characterization method selected on the ASSAY statement below.

Mandatory entries:

number, name{, , alias} / ... For each component, its number in the component list for this simulation followed by its library name (not the full name). Separate one components entry from the next using the / character.

Select components from the list in Chapter 1 of the SimSci Component and Thermodynamic Data Input Manual.) For convenience, some components have more than one allowable name.

Optionally, you may also enter an alias (up to 16 characters) for a component, which will be used in the output reports. If you enter an alias, you must have two commas before it.

You may enter the components in any order but there must be no gaps in the component number sequence and each component number must be used only once. This rule applies to all defined components, including Petroleum pseudocomponents entered using the PETROLEUM statement below, but does not apply to petroleum fractions generated by the program from ASTM curves.

BANK Selects order of component databanks which are searched for pure components. The entries allowed are SimSci or PROCESS.

Optional entries: (For details, refer to Chapter 1, SimSci Component Data Input Reference, in the SimSci Component and Thermodynamic Data Input Manual.)

FILL Specifies that SimSci property prediction methods be used for components missing library or user-supplied data.

number, name, MW, std liquid density, NBP/...

You may supply a name of up to 16 characters for each component. The name is used in the output reports. You must supply at least two of the three quantities: molecular weight, gravity and normal boiling point. The remaining value is calculated. You may use qualifiers to define units of measurement for gravity and/or normal boiling point.



Example:PETRO 5, CUT11, 91,64,180/6, CUT12,100,,210/ & 7, CUT13,120,55,280/8, CUT14,150,,370/ & 9, CUT15,200,40,495/10, CUT16,245,,590/ & 11, CUT17,300,30,687/12, CUT18,360,,770

ASSAY

Optional statement. Used to specify the method by which PIPEPHASE calculates the properties of defined pseudocomponents or those generated from assay data.

Mandatory entries:

Example:ASSAY CHAR = SIMSCI, MW = CAV80, GRAV = WATSONK, * CONVERSION = API87, CURVEFIT = VER6

The number must follow the rules described above under LIBID.

If a name is not given, PIPEPHASE will assign a name based on the normal boiling point.

If you omit any data item, you must retain the embedded comma.

CHARACTERIZE = CAVETT Define the method to be used for calculating critical properties and enthalpies of pseudocomponents. Options are described in Table 4-11, Characterization Methods.

MW = CAV80 Define the method to be used for calculating molecular weights of pseudocomponents. Options are described in Table 4-10.

CONVERSION = API94 Selects the method for inter-conversion between ASTM-D86 and TBP distillation curves. Options are described in Table 4-13, Inter-Conversion Methods.

CURVEFIT = VER6 Defines the method for determining end points of petro cuts. Options are described in Table 4-14, CURVEFIT Methods.

GRAVITY = WATSONK Define the method to be used for calculating gravities for pseudo-components when only the average gravity of a curve is given. Options are described in Table 4-12.

Other entries: (For details, refer to Chapter 1, SimSci Component Data Input Reference, in the SimSci Component and Thermodynamic Data Input Manual.)

FIT = SPLINE Selects the curve fitting procedure for user supplied assay data.

TBPIP = 1, TBPEP = 98

Define the volume percents for determining the initial point (IP) and end point (EP) temperatures when specifying streams and reporting assay curves at output time.

NBP = Designates the method used for calculating the normal boiling point of narrow cuts.


COMPONENT Data Category of Input > ASSAY …

Table 4-10: Molecular Weight Methods

Table 4-11: Characterization Methods

Table 4-12: Gravity Methods used in PIPEPHASE

Table 4-13: Inter-Conversion Methods

Table 4-14: CURVEFIT Methods

Method Description

SIMSCI Method developed by SimSci to match the API Technical Data Book method for 300 to 800oF boiling components and to provide a better match to the available field data both above and below that temperature range.

EXTAPI 1980 API Technical Data Book method with adjustment for components boiling below 300oF to match known pure component data better. Also known as the CAVETT80 method.

CAVETT Old (pre-1980) API Technical Data Book method

Method Description

CAVETT CAVETT is used for critical constants and ideal gas enthalpies. Yen-Alexander is used for vapor pressures. Edmister is used for acentric factors.

SIMSCI SimSci’s extension of the CAVETT method is used for all properties. Also known as the Twu method.

LK Lee-Kesler is used for all properties.

Method Description

WATSONK Assumes constant Watson K for all components based on TBP temperatures.

PRE301 Assumes constant Watson K for all components based on ASTM temperatures.

Method Description

API63 This method is taken from the API Technical Data Book prior to the 1987 edition and uses a procedure developed by W.C. Edmister, et.al.

API87 This is the method published in the 1987 API Technical Data Book which was developed by Riazi and Daubert.

API94 This is the method detailed in the 1994 API Technical Data Book which was developed by Daubert, T.E.. This method uses an approach similar to that of the API 1963 procedure, which always produces a monotonic TBP curve.

Method Description

VER6 This method generates a quadratic using the first 3 (for IP) or last 3 (for EP) supplied data points. It uses the slope of this curve to linearly extrapolate to the appropriate end point (0%) or 100%). This may artificially introduce an inflection point in the data curve. Select this option to reproduce results from older PIPEPHASE version (upto 9.2.1)

IMPR This method uses a quadratic spline to more accurately locate missing end points.



CUTPOINTS

Optional statement. Used to define the TBP cut points for components defined by assay curve.

Mandatory entries:

Example:CUTPOINTS TBPCUTS(F)=100,800,20/ 1000, 10/ 1200,8 CUTPOINTS TBPCUTS(F)=100,1200,38

MWSPGRAPIACENTRICZC

Optional statements. Define constant properties of pure components.

Mandatory entries:

Example:MW 1, 59.3/4, 76.5

TC()PC()NBP()STDDENSITY()

Optional statements. Define constant properties of pure components. A qualifier may be used to specify units of measurement.

Mandatory entries:

Example:STDD(LBFT3) 4,45/7,50

TBPCUTS()= t0, t1, n1{/t2, n2/..}

t0 is the start temperature for the whole assay, t1 is the end temperature for the first group and n1 is the number of cuts in the first group. Then, for each subsequent group of cuts, enter the end temperature for the group and the number of cuts in that group.

The default is 100, 800, 28/1200, 8/1600, 4

number1, value1/number2, value2/ ...numberN, valueN

The number corresponds to the components number on the LIBID statement.




COMPONENT Data Category of Input > VC …

VC

Optional statement. Defines critical volume of pure components. Qualifiers may be used to specify units of measurement and basis.

Mandatory entries: :

Example:

VP()ENTHALPY()CP()LATENT()DENSITY()VISCOSITY()CONDUCTIVITY()SURFACE()

Optional statements. Define pure component properties that vary with temperature. Where appropriate, qualifiers may be used to specify phase, temperature unit, property units and basis. Properties are listed in Table 4-15.

Table 4-15: Pure Component Variable Properties in PIPEPHASE

You may enter either coefficients of an equation or tabular data.



VC(CC,M) 1, .09 Note: This is equivalent to 90 cc/gm mole.

Property Keyword Phase* Property Units Basis

Density DENSITY() L density M or WT

Enthalpy ENTHALPY() I or L energy M or WT

Solid specific heat CP() heat capacity M or WT

Latent heat of vaporization

LATENT() energy M or WT

Vapor pressure VP() L pressure

Viscosity VISCOSITY() V or L viscosity

Thermal conductivity COND() V or L conductivity

Liquid surface tension SURFACE() surface tension

*Phases are: I ideal gasV vaporL liquid



Mandatory entries: Coefficient form:

Optional entries:

Mandatory entries: Tabular form:

Example:DENSITY(L,C,LBFT3) TABULAR = 60, 80, 100/1,55.5,43.7/2, & 45.8,,40.2ENTHALPY(I,C,KCAL/KG,M) TABULAR=100,140,180/1,700000, & 825000,910000/ & 2,410000, ,470000VP(C,MMHG) CORR=21, LN, DATA= 1,,, 14.321, -1068, 60.3/ & 2,,, 16.15, -1372, 1.7

CORRELATION The correlation form for equation based data. See Chapter 1, SimSci Component Data Input Reference, in the SimSci Component and Thermodynamic Data Input Manual, for equation forms.

Note: Only equation 1 may be used for CP.

DATA = Data entry for equation based correlations. The format is: DATA = i, tmax, tmin, C1, ..., C8/...

i corresponds to the components number on the LIBID statement.

tmax, tmin are temperature limits for the data. They must be entered for Chebychev equations, and are optional for others. If omitted, the embedded commas must be retained.

C1,...,C8 are equation coefficients.

EXPFAC= Exponential factor. Only used in equations 3 and 4.

LN or LOG Select the logarithmic base e (LN) or 10 (LOG). Only used in equations with logarithmic terms.

TABULAR = Data entry for tabular data. The format is: TABULAR = t1, t2, .../i, p1, p2, .../...

t1, t2,... are temperatures at which tabular data are entered.

i corresponds to the components number on the LIBID statement.

p1, p2,... are data values at temperatures t1, t2,... . A minimum of one value must be given. You need not provide a value for every temperature point but if you skip a value you must retain the embedded comma.


NETWORK Data Category of Input > Overview …

NETWORK Data Category of Input

Overview

The NETWORK Data Category of input defines calculational methods. This category is only needed to control the network convergence algorithm.

Table 4-16: NETWORK Data Category of Input

NETWORK

Mandatory statement. Introduces the category.

Mandatory entries: NoneOptional entries: None

SOLUTION

Optional statement. Selects the solution method and sets switches for the convergence of a network. If you omit this statement, the PBALANCE method will be used with the defaults shown below. See Pressure Balance Method, p. 6-34, for details of the application of these parameters



NETWORK None

{SOLUTION} PBAL or MBAL, MAXITER = 20, FLOWALLOC = 1, PRELIMINARY = 1, FINAL = 1, SUBITERATION = 200, RELAXATION = 0.25, DAMP = 0.25, EXPLICIT, NOFR, QDAMP =, PDAMP = , STEP = 1, SLIP = 5, HALVINGS = 3, NOLOOP=0, CHECK, CHOKE = 1, WELLS, PROP=0, SCALE=1.0, SYMMETRIC, LINKS, ANSARI, XIAO, QUICK, KEEPSHUT

p. 40

{TOLERANCE} PTOL(psia)= .0001, QTOL()= 1, TTOL() = .001, RATE()=1.0, PRES()=2.0, QLOW=, PERT= .01, NEWACC

p. 44

{ACCELERATION} INTERPOLATION, NPRESS = 0, NTEMP = 0, PMIN = , PMAX = , TMIN = , TMAX = , STOP, ISOTHERMAL = 1

p. 44

PBAL or MBAL Use one of these to specify the network solution algorithm. PBAL invokes the Pressure Balance algorithm, MBAL the single-phase algorithm. MBAL can only be used with single-phase gas or liquid systems.

MAXITER = 20 Maximum number of iterations for the PBALANCE method.



FLOWALLOC = 1 Controls the initial estimate for flowrates in PBALANCE networks only.Use FLOWALLOC=1 to estimate initial flowrates based on diameters of the first pipe in the links.Use FLOWALLOC=2 to estimate initial flowrates based on the frictional resistance of each link.Use FLOWALLOC=3 to estimate initial flowrates based on nodal mass (MBAL) conservation.Use FLOWALLOC=4 to use flowrates and pressure from a previous solution of the network, to be read from a restart file.

PRELIMINARY = 1 The number of continuation steps to be used to compute the preliminary solution for the MBAL method and for FLOW=3 in the PBAL method.

FINAL = 1 The number of final continuation steps required to move the pressure field predicted by the preliminary solution to the final rigorous solution. This is applicable to the MBAL method and FLOW=3 in the PBAL method

SUBITERATION = 200 Maximum number of iterations to be performed in each continuation step. This is applicable to the MBAL method and FLOW=3 in the PBAL method

RELAXATION = 0.25 Extent of partial correction from iteration to iteration for the pressure field. Values can be between 0 and 1.0. This is applicable to the MBAL method and FLOW=3 in the PBAL method

DAMP = 0.25 Extent of partial correction from iteration to iteration for the preliminary continuation stage. Values can be between 0 and 1.0. This is applicable to the MBAL method and FLOW=3 in the PBAL method

EXPLICIT Applicable only to a single-phase gas or liquid system. When present, initial estimates are obtained from the Blasius friction factor approximation. Otherwise, the implicit Colebrook/BBM approach is used. This is applicable to the MBAL method and FLOW=3 in the PBAL method

NOFR Include this keyword to specify that no flow reversals are to be permitted within links during the solution of a network. Applicable to PBAL method.

QDAMP = Limits the magnitude of the flowrate adjustment for any link at each iteration within a PBALANCE network. If a link flowrate change exceeds QDAMP, the magnitude of the change vector is normalized such that the magnitude of the vector is reduced but the direction of the adjustment vector is not changed. The units of QDAMP are fixed as:

FLUID TYPE UNITSCompositional & steam (MLBHR) Gas & condensate (MCFD) Liquid & blackoil (BPD)

This feature is useful when large flowrate fluctuations and convergence instabilities are observed in the iteration history of a network run, commonly seen in a large, highly looped network. Damping the flowrate changes to a small value may lead to a more stable iteration scheme but may result in slower convergence. You may need to increase the number of iterations to achieve convergence to within the required tolerance.

PDAMP = Similar to QDAMP, but applied to node pressure changes. Pressures are in units of psi. Applicable to PBAL method.

STEP = 1 Use this keyword to enable the Newton-Raphson algorithm to converge without internal limits.


NETWORK Data Category of Input > SOLUTION …

SLIP = 5 Applicable only to FLOWALLOCATION = 3. Use this keyword to specify the slope angle above which the BBM model used to initialize the flow field reduces to the no-slip formulation. Units are degrees.

HALVINGS = 3 Number of interval halvings allowed in each successive iteration. Applicable to PBAL method.

NOLOOP=0 Use this keyword to generate a report of the occurrence of closed loops during intermediate PBAL iterations. Use NOLOOP=1 to obtain a warning if closed loop flow occurs during PBAL iterations. If you use NOLOOP=2, PIPEPHASE will print the warning and, in addition, try to prevent the closed loop flow from forming.

CHECK When present, regulators (unidirectional check valves) are allowed to pass a small backward flow.

CHOKE = 1 Controls the broadening of the critical flow regimes in Choke valves.

Use CHOKE = 1 to allow exponential broadening.

Use CHOKE = 2 to allow linear broadening.

Use CHOKE = 3 to invoke a rigorous critical flow approach for chokes.

The flowrate through a choke depends on the pressure drop through the choke when the flow is subcritical. When a choke is in 'critical flow' the flowrate through the choke depends only on the inlet pressure. Further reduction of the downstream/outlet pressure below the critical pressure (outlet pressure at the on set of critical flow) has no effect on the flowrate. When this happens Newton-based methods cannot be applied directly because the dpout/dq derivatives go to infinity. PIPEPHASE solves networks where chokes are in critical flow using three mutually exclusive options.

CHOKE=1: The infinite derivative is replaced by a exponential extension of the choke performance curve.

CHOKE=2: The infinite derivative choke performance curve is replaced by a high but finite valued user defined slope or derivative using a linear extension of the choke performance.

The above two options allows the network algorithm to use Newton methods to proceed to a solution. Due to the high value of the derivative the network becomes sensitive and may sometimes fail to converge. These two options are available for the Fortunati and Ueda choke models.

CHOKE=3: PIPEPHASE solves for the maximum possible flow (critical flow) for the well for a given source pressure (user-specified reservoir or bottom hole pressure). If the network tries to flow more than the critical flowrate, the link QMAX logic is invoked based on the critical flowrate which acts as the maximum allowable flowrate for that well/link.

The solution obtained accurately reflects the critical choke flow behavior and the resulting network solution. At this time, this option is invoked only with the Perkins choke model. This option works only for chokes in source links where the link source pressure is fixed.

WELLS Use this keyword to prevent well flows from falling below the minimum required to transport fluid in a two-phase system.



PROP=0 Controls the number of fluid property evaluations that are performed in each link for the PBAL (FLOWALLOC=3) initialization procedure.

PROP=0 Fluid properties are evaluated only once per link at an average pressure and temperature.

PROP=1 Fluid properties are evaluated for each device based on conditions at the start of the device.

PROP=2 Fluid properties are evaluated for each device based on conditions at the end of the device. This invokes an iterative calculation for each device which consumes more computing time and thus should only be used if the initialization procedure needs help to produce an acceptable initial estimate for the PBAL algorithm.

SCALE=1.0 Allows the user to control the extent of the Newton-Raphson correction to the network pressure and link flow distribution. This number is a fraction between 0 and 1. When the value is 1.0, a complete Newton-Raphson correction is made to the estimated flow and pressure distribution. When this value is less than 1.0, a fractional Newton-Raphson correction is made during the PBAL iteration process. The value of the fractional correction is the value of the parameter assigned to SCALE. Occasionally, fractional values of SCALE can stabilize the Newton-Raphson iteration process. However, extremely small fractional values can also slow down the calculation procedure.

LINKS With this option, PIPEPHASE generates flow tables at the start of the calculations that relate flowrate to exit pressure and exit temperature in all links that originate with a source that has a fixed inflow pressure boundary conditions. When available, the tables are then used in the place of the normal pressure traverse procedure to compute exit pressures and temperatures for links. This option can potentially speed up the PBAL iteration procedure in PIPEPHASE.

XIAO With this option, the FLOW=3 allocation method will use the XIAO mechanistic model instead of the default BBM model to estimate the flowrate in pipes.

ANSARI With this option, the FLOW=3 allocation method will use the Ansari mechanistic model in tubes and annuli instead of the default BBM model to estimate flowrates.

SYMMETRIC With this option, the FLOW=3 allocation method will approximate the Jacobian Matrix used in the Newton-Raphson iteration procedure as a symmetric matrix. This option has the potential of increasing the computational speed of the FLOW=3 allocation method.

QUICK With this option, the FLOW=3 allocation method will (1) approximate the Jacobian Matrix as a symmetric matrix, and (2) will use an approximate method to compute flowrate derivatives. This option has the potential of further increasing the computational speed of the FLOW=3 allocation method.

KEEPSHUT Allows wells that have been closed to remain closed, unless the user explicitly opens the wells again. This option should not be used with optimization, because if the wells are closed in during the previous cycle, if may eliminate the best cycle.


NETWORK Data Category of Input > TOLERANCE …

Example:SOLUTION PBAL, MAXITER=30, FLOWALLOC=2, PRELIM=2, FINAL=2, & SUBITER=100,RELAX=0.5, DAMP=0.5, EXPLICIT, NOFR, QDAMP=10, & PDAMP=0.5, HALVINGS=4, NOLOOP,CHECK, CHOKE=2

TOLERANCE

Optional statement. Defines the criteria for convergence of networks that require iterative calculations.


For PBAL network solution methods:

Example:TOLERANCE PTOL = .0003, QTOL = 2, TTOL = .0005

ACCELERATION (for PBAL Network Method Only)

Optional statement. Forces PIPEPHASE to interpolate from tabulated fluid properties during intermediate iterations instead of carrying out rigorous property calculations at every iteration in every link. Rigorous flashing is carried out on the final iterations unless the STOP keyword is used.

PTOL(psia) = .0001

Pressure tolerance for MBAL network solution and for network initialization under FLOWALLOC = 3.

QTOL() = 1 Flow tolerance for MBAL network solution and for network initialization under FLOWALLOC = 3. Units depend on the fluid type:Liquid and blackoil bbl/day Gas and gas condensate MCFD Compositional and steam MLBHR

TTOL() = .001 Temperature tolerance for MBAL network solution method only.

QLOW()= Default minimum flowrate for all pressure-specified sources in the network. PIPEPHASE will zero out flows for those sources that fall below the specified minimum value.

PERT= .01 Specify the rate perturbation for the network solution.

NEWACC Used to handle high velocity fluids for near critical flow applications. This option determines fluid properties in a pipe segment from the average of the inlet and outlet properties. The inlet and outlet velocities directly calculate the pressure drop due to acceleration.

PRES()=2.0 Pressure tolerance for PBAL solution method.

RATE()=1.0 Used to improve convergence in networks with chokes in critical flow (CHOKE=2 option).



Mandatory entries: :

Optional entries:

Example:ACCELERATION INTERPOLATION, NPRESS = 10, NTEMP = 10, & PMIN = 1, PMAX = 100, TMIN = 10, TMAX = 500, STOP, &ISOTHERMAL = 2

INTERPOLATION Use this keyword to switch on the interpolation procedure.

NPRESS = 0 Number of equally spaced pressure points.

NTEMP = 0 Number of equally spaced temperature points in the matrix. NPRESS * NTEMP must not exceed 400.

PMIN()= Minimum pressure in the matrix

PMAX()= Maximum pressure in the matrix

TMIN()= Minimum temperature in the matrix

TMAX()= Maximum temperature in the matrix

STOP When convergence is reached using the interpolated properties, use of this keyword stops the calculations . Without this keyword, calculations continue until convergence is reached using rigorous property values.

ISOTHERMAL = 1 Specifies the temperature at which properties are looked up in the matrix. ISOTHERMAL = 1 looks up properties at the local ambient temperature.ISOTHERMAL = 2 looks up properties at the local upstream node temperature.ISOTHERMAL = 3 looks up properties at TMIN.


THERMODYNAMIC Data Category of Input > Overview …

THERMODYNAMIC Data Category of Input

Overview

The Thermodynamic Data Category of input defines the methods that PIPEPHASE uses to determine phase separation and transport properties in compositional runs. You need this category only if you have specified that the fluid is compositional on the Calculation statement in the General Data category.

Chapter 2, SimSci Thermodynamic Data Input Reference, in the SimSci Component and Thermodynamic Data Input Manual describes all the features of the SimSci Thermodynamic Data system. Many of these features are not used in PIPEPHASE because they are not relevant to pressure drop through pipes and fittings.

Of those that are relevant, the commonly used ones are described here in detail. The rest are summarized and you should refer to the SimSci Thermodynamic Data Input Reference cited above.

Table 4-17a: Thermodynamic Data Category of Input


THERMODYNAMIC None p. 48

METHOD {SYSTEM()=, KVALUE()=, ENTHALPY()=, DENSITY()=, TRANSPORT= PURE, VISCOSITY()=, CONDUCTIVITY()=, SURFACE=, SET = , DEFAULT}

p. 48

WATER DECANT=, {GPSA, SOLUBILITY=SIMSCI, PROPERTY=SATURATED}

p. 52

BWRS i, j, kij/ ... p. 53

LKP i, j, kij/ ... p. 53

PR i, j, kija, kijb, kijc/ ... p. 53

SRK i, j, kija, kijb, kijc/ ... p. 53



Table 4-17b: Other Statements to Table 4-17a

Other Statements For details, refer to Volume 2, of the SimSci Component and Thermodynamic Data Input Manual.

KVALUE ENTHALPY DENSITY

Used to identify non-default databanks and methods of calculating missing data.

KDATA Allows user-supplied K-value data.

HEXAMER, HOCV, TVIRIAL, IDIMER, RK1, RK2, SRKKD, SRKM, SRKH, PRP, PRM

Allows user-supplied binary interaction data for equations of state and generalized correlations.

NRTL, UNIQUAC, WILSON, VANLAAR, MARGULES, FLORY, IDEAL, AZEOTROPE, INFINITE, MUTUAL

Allows user-supplied binary interaction data for liquid activity methods.

PHI Used to identify vapor fugacity databanks.

HENRY, SOLUTE, HENDATA

Used to identify Henrys Law databanks.

UNIFAC,UNIFTn, UNFV

UNIFAC method UNIWAAL method Group contribution data for UNIFAC and/or UNIWAALS.

PAnn, SAnn, VAnn Supplies pure component alpha formulations for PR, SRK and UNIWAAL.

TC, PC, VC, ZC, ACENTRIC, NBP, MOLVOL, DIPOLE, RADIUS, SOLUPARA, RACKETT, WDELT

Used to specify pure component data for use with a specific thermodynamic method in place of the data input in the Component Category.


THERMODYNAMIC Data Category of Input > THERMODYNAMIC …

THERMODYNAMIC

Mandatory statement for compositional fluids and mixed compositional/non-compositional fluid models such as the compositional blackoil model. Introduces the category.


METHOD

Optional statement. Defines the methods to be used for calculating thermodynamic properties and transport properties of the flowing fluid. Choose systems with predefined methods for all properties or choose individual methods for each property.

If you want to use different methods to calculate properties of different sources, use multiple METHOD statements. Identify each METHOD statement using a SET keyword and refer to that identifier with the SET keyword on the SOURCE statement in the Structure Category.

Mandatory entries: You must specify either SYSTEM or KVALUE, ENTHALPY and DENSITY. All other entries are optional.

Optional entries:

SYSTEM() = Select a thermodynamic system from Table 4-18. The SYSTEM will allocate methods for calculating K-values, enthalpies and densities. If you select a SYSTEM, you can still override one or more of the individual methods by using the other keywords on this statement.

Use a qualifier to denote which type of equilibrium calculations are to be performed. Allowable qualifiers are:

SYSTEM VLE vapor-liquid VLLE vapor-liquid-liquid

KVALUE() = ENTHALPY() = DENSITY() =

Select methods from Table 4-19 for calculating K-values, enthalpies, and densities. If you have selected a SYSTEM, you do not need these keywords; use them if you want to override the individual methods automatically selected as part of the predefined SYSTEM.

Use qualifiers to denote which type of equilibrium calculations are to be performed and the phases to which the methods apply. Allowable qualifiers are:

KVALUE VLE (or none) vapor-liquid LLE liquid-liquid VLLE vapor-liquid-liquid

ENTHLPY VL (or none) both vapor and liquid V vapor only L liquid only



If you want to specify a different method for different phases, you may have more than one KVALUE entry. However it is done, whether with SYSTEM or KVALUE or a combination, you must include all phases present in the simulation.

For ENTHALPY and DENSITY you must specify methods for both vapor and liquid either by specifying a method for VL or a method for V and a method for L.

DENSITY VL (or none) both vapor and liquidV vapor only L liquid only

TRANSPORT = Select a transport system from Table 4-20. TRANSPORT will allocate methods for calculating viscosity, conductivity and surface tension. If you select TRANSPORT, you can still override one or more of the individual methods by using other keywords on this statement.

VISCOSITY() =CONDUCTIVITY() =SURFACE =

Select methods from Table 4-21 for calculating conductivity, surface tension and viscosity. If you have selected a TRANSPORT system, you do not need these keywords; use them if you want to override the individual methods automatically selected as part of the predefined TRANSPORT system.

Use qualifiers to denote the phases to which the methods apply. Allowable qualifiers are:

VISCOSITY VL (or none) both vapor and liquidV vapor only L liquid only

CONDUCTIVITY VL (or none) both vapor and liquid V vapor only L liquid only

SURFACE none liquid onlyFor VISCOSITY and CONDUCTIVITY you must specify methods for both vapor and liquid either by specifying a method for VL or a method for V and a method for L.

SET = Up to 12 alphanumeric characters. Identifies this METHOD statement. Needed only when multiple METHOD statements are used. Referenced using the SET keyword on the SOURCE statement in the Structure Category of input.

DEFAULT Identifies the default method set. When a SOURCE statement in the Structure Category does not explicitly specify a SET, the default method set is used. If no METHOD statement has the DEFAULT keyword, the first METHOD statement in the input is used as the default set. Only one METHOD statement may have the DEFAULT keyword.

Other entries: (For further information, refer to Chapter 2, SimSci Thermodynamic Data Input Reference, in the SimSci Component and Thermodynamic Data Input Manual.)

PHI Method to be used to compute pure component and mixture vapor fugacity coefficients for liquid activity methods.

HENRY Used to model dissolved gases in a liquid solution for liquid activity methods.


THERMODYNAMIC Data Category of Input > METHOD …

Example:METHOD SYSTEM=SRK, TRANS=PETRO, SET=MYSET1METHOD KVALUE=SRK, ENTHALPY=SRK, DENS(L)=API, DENS(V)=SRK, & VISC(V)=PETRO, VISC(L)= PURE, COND=PETRO, SURFACE=PURE,& DEFAULT, SET=MYSET2METHOD SYSTEM=SRK, KVALUE(LLE)= NRTL, KVALUE(SLE) = VANTHOFF

Table 4-18: Methods Used by Predefined Thermodynamic Systems

For other systems, refer to Chapter 2, SimSci Thermodynamic Data Input Reference, in the SimSci Component and Thermodynamic Data Input Manual, Table 2.1.4-1.

System K-value Enthalpy Density (V) Density (L)

BK10 BK10 JG IDEAL API

BWRST BWRST BWRST BWRST BWRST

CS CS CP SRK API

GS GS CP SRK API

LKP LKP LKP LKP API

PR PR PR PR API

SRK SRK SRK SRK API



Table 4-19: Thermodynamic Calculation Methods

For other methods, refer to Chapter 2 in the SimSci Component and Thermodynamic Data Input Manual, Table 2.1.3-1.

Table 4-20: Methods Used by Predefined TRANSPORT Systems

Table 4-21: Transport Property Calculation Methods

Method Keyword K-value Enthalpy Density(L) Density(V)

API Method API Yes

BWRS-Twu BWRST Yes Yes Yes Yes

Braun K-10 BK10 Yes

Chao-Seader CS Yes*

Curl-Pitzer CP Yes

Grayson-Streed

GS Yes*

Johnson-Grayson

JG Yes

Lee-Kesler LK Yes Yes Yes

Lee-Kesler-Plcker

LKP Yes Yes Yes Yes

Peng-Robinson

PR Yes Yes Yes

Redlich-Kwong

RK Yes

Soave-Redlich-Kwong

SRK Yes Yes Yes

* Not to be used for systems with more than a total of 5% molar carbon dioxide and hydrogen sulfide or for fluids above their critical points.

System Viscosity Conductivity Surface Tension

PETRO (default) PETRO PETRO PETRO

PURE PURE PURE PURE

TRAPP TRAPP TRAPP PETRO

TACITE LBC TRAPP PARACHOR

Method Keyword Viscosity Conductivity Surface Tension

Library Data PURE Yes Yes Yes

Hydrocarbon predictions PETRO Yes Yes Yes

TRAPP Method TRAPP Yes Yes

API Technical Data Book API Liquid only

Woelfin Method (Tight correlation using PETRO or PURE method)

TSWOELF or TWOELF

Liquid only


THERMODYNAMIC Data Category of Input > WATER …

WATER

Optional statement. Defines the method to be used for calculating water and steam properties.

Mandatory entries:

Optional entries:

Example:WATER DECANT=ON, GPSA, SOLU=KERO, PROP=STEAM

Table 4-22: Water Solubility Calculation Options

Woelfin Method (Medium correlation using PETRO or PURE method)

MSWOELF or MWOELF

Liquid only

Woelfin Method (Loose correlation using PETRO or PURE method)

LSWOELF or LWOELF

Liquid only

Lohrenz-Bray-Clark LBC Liquid only

Parachor Method PARACHOR Yes

Heavy Oil Heavy Liquid only

DECANT = When ON, water is treated as a special component, its solubility in the hydrocarbon phase is calculated and the non-dissolved water put into a separate phase. When OFF, water is treated as being fully soluble in the rest of the stream. When SRK, PR, GS, CS, GSE, CSE, IGS, LKP, BK10 or BWRS methods are used, DECANT is optional and defaults to ON.

GPSA Used with DECANT = ON to specify that water partial pressures are calculate using the GPSA Data Book Figure 20-3. If this keyword is not present, steam tables are used.

SOLUBILITY = SIMSCI Used to specify the method of computing the solubility of water in the hydrocarbon phase. Options are in Table 4-22.

PROPERTY = SATURATED

The calculation basis of pure water properties. Options are in Table 4-23.

SIMSCI Calculations are based on the solubility of water in a number of common components, including hydrocarbons and non-hydrocarbon gases. See Chapter 2, SimSci Thermodynamic Data Input Reference, in the SimSci Component and Thermodynamic Data Input Manual, for details.

KEROSENE Calculations are based on the solubility of water in kerosene, as presented in the API Technical Data Book, Figure 9A1.4.

Method Keyword Viscosity Conductivity Surface Tension



Table 4-23: Water Property Calculation Options

BWRSLKP

Optional statements. Define the interaction parameters for the BWRS and LKP equation of state.

Mandatory entries:

Example:BWRS 2,3,0.055/3,4,0.008

PRSRK

Optional statements. Define the interaction parameters for the Peng-Robinson and Soave-Redlich-Kwong equation of state.

Mandatory entries:

Example:PR 2,3,0.001, 0.054, 3.8/3,4,0.0089, 0.0006, 0.5601

EOS Solubility is calculated from equation of state water K-values using water-hydrocarbon interaction parameters.

SATURATED Properties are based on vapor/liquid curves. Adequate for most simulations.

STEAM Properties are calculated using the Keenan and Keyes equation of state for water. Use this method when water is present as a superheated vapor.

i, j, kij /... Enter component pair numbers followed by the numerical value of the binary interaction coefficient for the pair. Multiple entries are separated by the “/” character.

i, j, kija, kijb, kijc / ... Enter component pair numbers followed by the numerical value of the binary interaction coefficients for the pair. Multiple entries are separated by the “/” character.


PVT Data Category of Input > Overview …

PVT Data Category of Input

Overview

The PVT Data Category of input defines properties of streams. This category is mandatory for blackoil, gas condensate, gas and liquid, and mixed compositional/non-compositional blackoil fluid models. It is optional for steam and mandatory for a compositional fluid only if you want to build and/or use property tables, or if you want to override the bulk liquid viscosity.

Table 4-24: PVT Data Category of Input

PVT



SET

Mandatory statement. The entries on this statement depend on the fluid type.


PVT None p. 54

SET SETNO=, {GRAVITY()=, CONTAMINANTS=0,0,0, COMP, CPRATIO=1.30, VISCOSITY()=, CP()=, FVF=, SGOR=}

p. 54

{ADJUST} TRESERVOIR()=, VISCOSITY()=, COMPRESSIBILITY()=, PRESSURE()=

p. 58

{LIFTGAS} GRAVITY()=, CONTAMINANTS=0,0,0 p. 59

{TABULAR} SETNO=, TEMPERATURE()=, PRESSURE()= p. 59

{FVF} DATA= p. 60

{SGOR()} DATA= p. 61

{VISCOSITY()} DATA= p. 61

{GRAVITY()} DATA= p. 61

{CORRELATION} {VISCOSITY()=, ZFACTOR=STANDING, FVF=VAZQUEZ, SGOR=VAZQUEZ, BLEND=VOLUMETRIC, INVERSION=, RATIO=}

p. 62

{DIMENSION} {MAXDIM=}

{GENERATE} SOURCE=, SETNO=,TYPE=, {TEMPERATURE()=, DT()=, NT()=, PRESSURE()=, DP()=, NP()=, GOR()=, PRINT=NONE, PLOT=NONE, PVTFILE=}

p. 64

{FILE} SETNO=, PVTFILE= p. 70



SET for Non-Compositional Liquid

Mandatory entries:

Optional entries:

Example:SET SETNO=1, GRAVITY(LIQUID,LBFT3)=49.7, CP(KCKGC)=0.525,&VISCOSITY(C,CP)=0,0.395/50,0.246

SET for Non-Compositional Gas

Mandatory entries:

Optional entries:

Example:SET SETNO=1, GRAVITY(GAS)=1.04, CPRATIO=1.45, CONT=0,0,0.2

SET for Steam

Mandatory entries:

SETNO= A numerical entry which identifies the set. This set number corresponds to a set number on one or more SOURCE statements in the Structure Data Category of input.

GRAVITY()= Defines the standard gravity of the fluid in gravity units. You must include a qualifier to specify whether the fluid is LIQUID or WATER. If you use LIQUID, correlations for liquid hydrocarbons will be used. If you use WATER, correlations for water properties will be used. Additionally, if you use WATER, you must enter a gravity value corresponding to a specific gravity of greater than or equal to 1.0.

VISCOSITY()=Viscosity Use this entry to define a constant viscosity or a log-log viscosity curve. You may enter either kinematic or dynamic viscosity by specifying the appropriate units. The format for the entry is: either VISCOSITY()=valueor VISCOSITY()=temp1,value1/temp2,value2

CP()= Use this entry to define a constant heat capacity for the fluid.

SETNO= A numerical entry which identifies the set. This set number corresponds to SOURCE statements in the Structure Data Category of input.

GRAVITY(GAS)= Defines the standard gravity of the gas in gas gravity units. If the unit is SPGR, it is relative to air at 60 F and 1 atmosphere. You must use the qualifier GAS.

CONTAMINANTS=0,0,0 Defines gas contaminants, which modify the correlated z-factor calculation. All three values are required. The format for the entry is: CONTAMINANTS=mole % N2, mole% CO2, mole% H2S

CPRATIO=1.30 Ratio of Cp/Cv.

SETNO= A numerical entry which identifies the set. This set number corresponds to SOURCE statement in the Structure Data Category of input.


PVT Data Category of Input > SET for Compositional Fluid …

Optional entries:

Example:SET SETNO=1, GRAVITY(WATER,LBFT3)=66

SET for Compositional Fluid

Mandatory entries:

Optional entries:

Example:SET SETNO=1, VISCOSITY(OIL,CP,F)=100,2.6/200,0.8

SET for Condensate

Mandatory entries:

GRAVITY(WATER,SPGR)=1.0

Defines the standard gravity of the liquid water in gravity units. You must use the qualifier WATER. If you do not want to override the default value, you can omit the entire PVT Data Category of input.


VISCOSITY()= Use this entry to define a constant viscosity or a log-log liquid viscosity curve.You may enter either kinematic or dynamic viscosity by specifying the appropriate units. The format for the entry is: either VISCOSITY()=valueor VISCOSITY()=temp1,value1/temp2,value2

You must use a qualifier to define the phase to which the data refer. Options are OIL, WATER and LIQUID for the hydrocarbon phase, the free water phase and the total liquid respectively. If multiple sets of two-point viscosity curves are supplied by the user, PIPEPHASE will blend these curves when the streams mix. If viscosity curves are specified, they must be specified for all sets. Only one set of single-point viscosity data is allowed.


GRAVITY()= Defines the standard gravities of the fluids. You must include a qualifier to specify whether the fluid is GAS, CONDENSATE or WATER. You must enter data for all three phases even if one or more is not present. Gravity units are used for CONDENSATE and WATER and gas gravity units for GAS. The value of the gravity of WATER must correspond to a specific gravity of greater than or equal to 1.0.



Optional entries:

Example:SET SETNO=1, GRAVITY(GAS,KGM3)=1.0, GRAVITY(WATER,SPGR)=1.03,& GRAVITY(COND)=58, CONT=1.3, 2.1, 0.0

SET for Compositional Blackoil (Compositional sets only)

There are two types of sets that are required for the compositional blackoil model. The first corresponds to the standard BLACKOIL PVT Set definition (see discussion below). The second (this set) corresponds to the compositional blackoil source definitions.

Mandatory entries: For compositionally-defined sources:

Optional entry:

SET for Blackoil

This set also applies to blackoil sources in the compositional blackoil model.

Mandatory entries:

CONTAMINANTS=0,0,0 Defines gas contaminants, which modify the correlated z-factor calculation. All three values are required. The format for the entry is:CONTAMINANTS=mole % N2, mole% CO2, mole% H2S

SETNO= A numerical entry which identifies the set. This set number corresponds to a set number on one or more CSOURCE statements in the Structure Data Category of input.

COMP This keyword indicates that the set is for a compositionally defined source under the compositional blackoil fluid model.

VISCOSITY(OIL)= Use this entry to define a constant viscosity or a log-log liquid viscosity curve. You may enter either kinematic or dynamic viscosity by specifying the appropriate unit.The format for the entry is: either VISCOSITY()=valueor VISCOSITY()=temp1,value1/temp2,value2

You must use the OIL qualifier to define the phase to which the data refer. If multiple sets of 2 point viscosity curves are supplied by the user, PIPEPHASE will blend these curves when the streams mix. If viscosity curves are specified, they must be specified for all sets. Only one set of single point viscosity data is allowed.


GRAVITY()= Defines the standard gravities of the fluids. You must include a qualifier to specify whether the fluid is GAS, OIL or WATER. You must enter data for all three phases even if one or more is not present. Gravity units are used for OIL and WATER and gas gravity units for GAS. The value of the gravity of WATER must correspond to a specific gravity of greater than or equal to 1.0.


PVT Data Category of Input > ADJUST (Blackoil only) …

Optional entries:

Example:SET SETNO=1, GRAVITY(OIL)=28, GRAVITY(WATER)=10.5,& VISCOSITY(OIL)=100,10/210,1, GRAVITY(GAS)=0.75,& CONT=1.3, 2.1, 0.0

ADJUST (Blackoil only)

Optional statement. Used for blackoil only. This statement must immediately follow the SET statement. The measured laboratory data on this statement adjusts the properties computed by the Standing correlation. You must specify STANDING for all properties on the CORRELATION statement. More than one ADJUST statement is allowed per run.

Note: Also applies to blackoil sources in the compositional blackoil model.

Mandatory entries:

VISCOSITY(OIL)= Use this entry to define a constant viscosity or a log-log liquid viscosity curve. You may enter either kinematic or dynamic viscosity by specifying the appropriate unit. The format for the entry is: either VISCOSITY()=value or VISCOSITY()=temp1,value1/temp2,value2

You must use the OIL qualifier to define the phase to which the data refer. If multiple sets of 2 point viscosity curves are supplied by the user, PIPEPHASE will blend these curves when the streams mix. If viscosity curves are specified, they must be specified for all sets. Only one set of single point viscosity data is allowed.

CONTAMINANTS=0,0,0 Defines gas contaminants, which modify the correlated z-factor calculation. All three values are required. The format for the entry is: CONTAMINANTS=mole % N2, mole% CO2, mole% H2S

FVF= This specifies the the blackoil formation volume factor correlation. Select on option from Table 4-25. If not specified, Pipephase will use the default correlation specified in the CORRELATION statement.

SGOR= This specifies the the blackoil Solution gas-oil ratio correlation. Select an option from Table 4-25. If not specified, Pipephase will use the default correlation specified in the CORRELATION statement.

TRESERVOIR()= Reservoir temperature. Corresponds to the first PRESSURE entry given below.

VISCOSITY()= Oil viscosity at bubble point conditions.

COMPRESSIBILITY()= Oil compressibility above the bubble point. Units are reciprocal pressure units.



Example:ADJUST TRESERVOIR(F)=160, VISCOSITY(CP)=2.1, COMPRESS=8E-6, & PRESSURE(PSIG)=1400,1000,400, FVF=1.23,1.21,1.17,& SGOR=449,297,191

LIFTGAS (Blackoil only)

Optional statement. Used for blackoil only. Defines lift gas properties when the GASLIFT calculation option is used or when a GLVALVE is present in a link.


Mandatory entries:

Example:LIFTGAS GRAVITY=0.75, CONTAMINANTS=1.5, 0.0, 0.25

TABULAR (Blackoil only)

Optional statement. Used for blackoil only. Supplies the temperature and pressure coordinates for the FVF, SGOR, VISCOSITY and GRAVITY statements that follow. The data supplied on these statements override those calculated by the program.


Mandatory entries:

PRESSURE()= Three pressures, separated by commas, in descending order. The first must be the bubble point pressure corresponding to TRESERVOIR. The last should be of the order of 200 psig. The middle value must be a value intermediate between the other two.

SGOR()= Three values of solution gas oil ratio, separated by commas, corresponding to the three PRESSURE values.

FVF()= Three values of volume formation factor, separated by commas, corresponding to the three PRESSURE values. FVF is the ratio of in-situ volume to stock tank volume.

GRAVITY()= Defines the standard gravity of the lift gas in gas gravity units. If the unit is SPGR, it is relative to air at 60 F and 1 atmosphere.

CONTAMINANTS=0,0,0 Defines lift gas contaminants, which modify the correlated z-factor calculation. All three values are required. The format for the entry is: CONTAMINANTS=mole % N2, mole% CO2, mole% H2S


TEMP()= At least two and no more than five entries may be given in ascending or descending order. The (units) entry may optimally be used to override the temperature units on the DIMENSION card.


PVT Data Category of Input > FVF (Blackoil only) …

Mandatory entries:

The TABULAR card is followed by cards of the form shown below where PNAME is a property name followed by qualifiers. The property values re entered in groups which correspond to the pressure groups.

Example:PNAME(qualifiers)DATA = v1,v2,...v10/...

FVF (Blackoil only)

Mandatory when TABULAR statement is used. Supplies Formation Volume Factor data for the matrix of temperatures and pressures on the TABULAR statement. This statement must follow the TABULAR statement. The data supplied on this statement override those calculated by the program.


Mandatory entries:

PRES()= At least three and no more than ten entries may be given in ascending or descending order. The (units) entry may optimally be used to override the temperature units on the DIMENSION card. Pressures are grouped with slashes(/), with one group to correspond to each TEMP entry. Each pressure group must include the bubble point pressure for the TEMP entry, with at least one pressure entry higher and one entry lower than the bubble point entry. The bubble point entry is designed with a ‘(BP)’ - immediately after the bubble point pressure entry.

DATA= Up to ten sets of up to five values. Each set must have the same number of values, separated by commas, as the number of TEMP values entered on the TABULAR statement. There must be the same number of sets, separated by the slash (/) character, as the number of PRESSURE values entered on the TABULAR statement.




SGOR() (Blackoil only)

Mandatory when TABULAR statement is used. Supplies Solution Gas Oil Ratio data for the matrix of temperatures and pressures on the TABULAR statement. This statement must follow the TABULAR statement. The data supplied on this statement override those calculated by the program.


Mandatory entries:

VISCOSITY() (Blackoil only)

Mandatory when TABULAR statement is used. Supplies live oil Viscosity data for the matrix of temperatures and pressures on the TABULAR statement. This statement must follow the TABULAR statement. The data supplied on this statement override those calculated by the program.


Mandatory entries:

GRAVITY() (Blackoil only)

Optional. Used only with TABULAR statement. One or two statements, with OIL and/or GAS qualifier, supply oil and/or gas gravities data for the matrix of temperatures and pressures on the TABULAR statement. These statements must follow the TABULAR statement. The data supplied on these statements override those calculated by the program.





PVT Data Category of Input > CORRELATION …

Mandatory entries:

Example:GRAVITY(OIL,LBFT3) DATA= .....

CORRELATION

Optional statement. Used for Blackoil and Non-Compositional Liquid and Gas.


Example:CORR VISCOSITY (LIQ)=USER, CONSTANTS = AA1, 3.383 /CC4, 34.5/…CORRELATION VISCOSITY(GAS)=KATZ, ZFACTOR=DRY


VISCOSITY()= Used with Blackoil, Liquid and Gas. Specifies the correlation for the viscosity calculations. Select an option from Table 4-25. You must use a qualifier to indicate whether the phase is LIQ, GAS or OIL. The default depends on the phase and the fluid. With Blackoil, use VISCOSITY(LIQ) to define the water-oil mixing rule.

ZFACTOR=STANDING Used with Blackoil and Gas. Defines the method to be used for gas compressibility calculations. Select an option from Table 4-25.

FVF=VAZQUEZ Used with Blackoil only. Defines the method to be used for formation volume factor calculation. Select an option from Table 4-25.

SGOR=VAZQUEZ Used with Blackoil only. Defines the method to be used for solution gas oil ratio calculation. Select an option from Table 4-25.

BLEND=VOLUMETRIC Used with Blackoil and Liquid. Defines the viscosity blending rule. Alternatives are VOLUMETRIC and INDEX.

INVERSION= Water fraction at the inversion point on a volume basis. Use this entry to adjust the calculation of water-oil mixture viscosity using one of the WOELFLIN viscosity mixing rules.

RATIO= Enter a curve of water volume fraction against viscosity multiplier. Use this entry to adjust the calculation of water-oil mixture viscosity using one of the WOELFLIN viscosity mixing rules. up to ten points may be entered. The format is:RATIO=water_frac1, multiplier1/water_frac2, multiplier2...

VISCOSITY (LIQ) = USER or DAQING

This keyword is required to define an user-defined viscosity correlation model. Up to 40 labels (maximum 16 characters) and corresponding constants can be specified. Entry of CONSTANTS data is optional. See Table 4-17a for user-defined labels and their default values. If required, default values can be defined constants.



Table 4-25: Property Correlations

Fluid Property Correlation Keyword

Liquid Hydrocarbon

VISC(LIQ) TUFFP Vazquez/Beggs VAZQUEZ

Beal-Standing/Chew-Conally STANDING

GLASO GLASO

Liquid Water VISC(LIQ) Beal BEAL

ASME Steam tables ASME

Gas VISC(GAS) Lee et al LEE

Katz, Carr et al KATZ

ZFACTOR Standing-Katz STANDING

Hall-Yarborough wet gas WET

Hall-Yarborough dry gas DRY

Blackoil VISC(OIL) TUFFP Vazquez/Beggs VAZQUEZ

Beal-Standing/Chew-Conally STANDING

GLASO GLASO

VISC (LIQ) Daqing DAQING

User USER

VISC(GAS) Lee et al LEE

Katz, Carr et al KATZ

Volumetric averaging AVERAGE

API Procedure 14b API

Woelflin for emulsions (tight correlation) TWOELF

Woelflin (medium correlation) MWOELF

Woelflin (loose correlation) LWOELF

SGOR TUFFP Vazquez/Beggs VAZQUEZ

Lasater LASATER

Standing STANDING

GLASO GLASO

FVF TUFFP Vazquez/Beggs VAZQUEZ

Standing STANDING

GLASO GLASO

ZFACTOR Standing-Katz STANDING

Hall-Yarborough wet gas WET

Hall-Yarborough dry gas DRY


PVT Data Category of Input > DIMENSION …

Table 4-26: Labels and Default Values Used for User Defined Correlations

DIMENSION

DIMENSION specifies the maximum number of tables and table size to be used for the problem. This is an optional entry. System defaults are available. The DIMENSION statement must occur before the first GENERATE statement.

The MAXDIM keyword specifies the maximum number and dimensions of the Type 2 blackoil tables. The number of tables (TtABL label), the number of pressures (PRES label), the number of temperatures (TEMP label), and the number of variables (VARI label). An example may be found at the end of this chapter.

The syntax is:

DIMENSION MAXDIM=label,number/ label,number/……

MAXDIM Labels:

Labels Default Values Labels Default Values

CUT1 0.006 CC1 1.562

CUT2 0.74 CC2 2.7183

C1 7.1546 CC3 -0.03702

C2 2.7885 CC4 35.0

C3 0.6 CC5 2.7183

C4 7.2799 CC6 3.5

C5 2.8447 CC7 35.0

C6 0.6 AA2 3.3811

C7 7.2244 CC8 0.3892

C8 2.8506 CC9 2.7183

C9 0.6 CC10 -0.02237

C10 1.0 CC11 50.0

C11 2.8461 CC12 2.7183

C12 2.7183 CC13 3.5

C13 7.0 CC14 1.0073

AA1 3.3811 CC15 35.0

Label Description

TABL Number of tables. Minimum and Default is 10

PRES Number of pressures. Minimum and Default is 30, Maximum is 150

TEMP Number of temperatures. Minimum and Default is 30, Maximum is 150

VARI Number of variables. Minimum and Default is 6. Maximum is 18



Example:DIMENSIONS MAXDIM=TABL,20/PRES,50/TEMP,10/VARI,

GENERATE (for Compositional)

Optional statement. Used only for compositional fluids. Causes a table of fluid properties to be created. This table can be used in the same run in which it is generated or stored for use in a future run. You cannot do both.

If you want to create and use the table in this run, you may have only one source and you must have a complete Structure Data Category of input. If the table is to be stored for use in a subsequent simulation, you must use the PVTGEN entry on the CALCULATION statement in the General Data Category of input. You can create more than one table but the only Structure statements allowed are those required to define a source. Refer to your platform Installation Guide for assistance on file management procedures for your operating system and computer hardware.

Note: The phase fraction generated in the Compositional PVT Table are Molar fractions.

Mandatory entries:

Optional entries:

Example:GENERATE SOURCE=FEED, SETNO=1, TEMP=0,DT=30, NT=16,& PRES=10,50,90,130,150, PRINT=LDEN,LVIS,LFRAC, PLOT=FULL

SOURCE= The name of the compositional source for which the table is to be created.

SETNO= If you are saving tables for a future run, this entry refers to the table number and is used on the FILE statement in the future run. If you are not saving the table, this entry must be the same as the set number on the SOURCE statement.

TEMPERATURE()=100,DT()=10, NT=10

Use these entries to define the temperatures at which the properties are to be calculated. The format is:TEMP=initial value,DT=increment,NT=number of values

You must define at least three and not more than twenty data points.

PRESSURE()=14.7, DP()=20, NP=10

Use these entries to define the pressures at which the properties are to be calculated. The format is:PRES=initial value,DP=increment,NP=number of values


PRINT=NONE PLOT=NONE

Options are FULL or NONE or a list of individual properties: PRINT=property, property, ...

Table 4-27 shows the keywords for the properties.

PVTFILE= Use this entry to specify an eight character prefix for the PVT data file. The extension is always .PVT and the default is {input file name}.PVT.


PVT Data Category of Input > GENERATE (for Blackoil) …

Table 4-27: Generated Properties Printed or Plotted

GENERATE (for Blackoil)

Optional statement. Used for Blackoil. Causes a table of fluid properties to be created. This table can be used in the same run in which it is generated or stored for use in a future run. Multiple blackoil GENERATE statements are allowed, one for each PVT set.

Stream mixing of blackoil tables is automatically done when needed for network calculations. Specify the correlation for the viscosity calculations. Select an option from Table 4-25. You must use a qualifier to indicate whether the phase is LIQ, GAS or OIL. You cannot do both liquid and gas. The default depends on the phase and the fluid. With Blackoil, use VISCOSITY(LIQ) to define the water-oil mixing rule.

If you want to create and use the table in this run, you may have only one source and you must have a complete Structure Data Category of input. If the table is to be stored for use in a subsequent simulation, you must use the PVTGEN entry on the CALCULATION statement in the General Data Category of input. You can create more than one table but

Property Phase Keyword

Fraction (Molar fraction)

Gas Liquid

GFRAC LFRAC

Molecular Weight Gas Liquid

GMW LMW

Surface Tension Liquid Water

LSURF WSURF

Density Gas Liquid Water

GDEN LDEN WDEN

Viscosity GasLiquid Water

GVIS LVIS WVIS

Enthalpy Gas Liquid Water Total Stream

GENTH LENTH WENTH TENTH

Thermal Conductivity Gas Liquid Water

GCON LCON WCON

The properties generated are: Oil formation volume factor Solution gas-oil ratio Live oil viscosity Oil gravity Free gas gravity



the only Structure statements allowed are those required to define a source. Refer to your platform Installation Guide for assistance on file management procedures for your operating system and computer hardware.

Old keywords for old functionality in the GENERATE statement for TYPE=1 tables:

SETNO,TEMPERATURE()=,DT()=,NT=,PRESSURE()=,DP()=,NP=6GOR()=

Mandatory entries:

Optional entries:

Example:GENERATE SOURCE=FEED, SETNO=1, TEMP=250, 50,&PRES=4000,1000,4, GOR=1236, PLOT=FULL

New keywords for new functionality in the GENERATE statement for TYPE=2 tables:

Mandatory entries: For Type=2:

SETNO= If you are saving tables for a future run, this entry refers to the table number and is used on the FILE statement in the future run. If you are not saving the table, this entry must be the same as the set number on the SOURCE statement.

TEMPERATURE()=100, DT()=10, NT=6

Use these entries to define the temperatures at which the properties are to be calculated. The format is: TEMP=initial value,DT=increment,NT=number of values


PRESSURE()=14.7, DP()=20, NP=6

Use these entries to define the pressures at which the properties are to be calculated. The format is:PRES=initial value,DP=increment,NP=number of values

GOR()= The formation GOR for which the PVT table is to be generated.

TYPE=1 Defines the type of blackoil table. Allowed values are 1(default) for Fixed GOR type tables or 2 for the new variable GOR PVT tables.

PLOT=NONE Use this keyword to control the output of plotted properties. Options are FULL or NONE. Property tables are always printed.

PVEC ( units)= Specifies an array of pressures. The number of pressures allowed depends on what was specified for the PRES label in the MAXDIM statement.

TVEC (units )= Specifies an array of temperatures. .The number of temperatures allowed depends on what was specified for the PRES label in the MAXDIM statement.

PRVEC=label, integervalue/label,integer value/……

The type 2 blackoil table always generates/uses 6 mandatory properties and 12 additional optional properties. This keyword specifies through standard labels (listed below), which optional properties are to be added in the Table. An integer value of 1 means that property is to be included. An integer value of 0 means that property is not to be included in the table. The 12 optional properties are listed below. If an optional property label is not specified, that optional property is not included..


PVT Data Category of Input > GENERATE (for Blackoil) …

Optional entries:

The PVT file will be always be generated in the same directory as the output file.

A blackoil PVT table can be used for any fluid with the same PVT set properties, independent of the gas oil ratio (GOR). When the tables are generated, a large GOR value is used to predict the solution gas oil ratio (SGOR) and other properties. When using the PVT tables, properties are obtained based on tabular data as impacted by the source GOR. The method for determining the accurate PVT properties above the bubble point is as follows:

• The bubble point pressure is calculated for the given temperature and source GOR.

• The solution gas oil ratio, water oil ratio, oil volume formation factor, water volume formation factor and liquid viscosity are obtained for the given temperature and pressure, with the pressure being limited to the bubble point pressure.

• The oil gravity, gas gravity, gas compressibility, gas viscosity and remaining proper-ties are obtained for the given temperature and pressure.

Table 4-28: Default Set of Properties (mandatory)

PRVEC keyword allows the user to specify additional property tables in addition to the default set.

PVTFIL=alpha-numeric character string

This keyword specifies the name of the PVT file to be generated for this blackoil PVT set. An automatic extension '.PVT' will be added to this string. The default name will be filename_setno_xx where 'xx' denotes the PVT set number.

FVFO Oil Formation Volume Factor

SGOR Solution Gas oil ratio

VISO Oil Viscosity

OILGRAV Oil Gravity

GASGRAV Oil Gravity

CO Oil Compressibility



Table 4-29: Additional Properties –Valid Labels

Example:GENERATE SETNO=4, PVTFILE=TEST_PVTGB2_SET4, TYPE=2,* TVEC=70,75,80,85,90,95,100,105,110,115,120,125,130, *PVEC=500,750,1000,1250,1500,1750,2000,2250,2500,2750,3000,3250,3500,3750,*PRVEC=VISW,1/CPO,1

This specification will generate a table with the following 6 mandatory properties and 2 optional (total 8) properties:

The old TEMPERATURE,DT,NT,PRESSURE,DP,NP keywords can be used for TYPE=1 tables

GOR will work only with TYPE=1 (old) PVT tables.

Old functionality: Only one black-oil GENERATE statements was allowed.

Note: Liquid viscosity is dependent primarily on temperature. For blackoil tabular data, viscosity may be a function of pressure below the bubble point to take into account gas that is dissolving into the liquid. Above the bubble point, the viscosity does not change significantly as a function of pressure. As a result, PIPEPHASE will use the viscosity at the bubble point pressure for pressures that exceed this value.

FVFW Water Formation Volume Factor

ZFAC Gas Compressibility

SGWR Solution Gas Water Ratio

VISG Gas Viscosity

VISW Water Viscosity

CW Water Compressibility

STOG Oil-gas Surface Tension

STWG Water-gas Surface Tension

STOW Oil-water Surface Tension

CPG Gas Specific Heat

CPO Oil Specific Heat

CPW Water Specific Heat

FVFO Oil Formation Volume Factor

SGOR Solution Gas oil ratio

VISO Oil Viscosity

OILGRAV Oil Gravity

GASGRAV Gas Gravity

CO Oil Compressibility

VISW Water Viscosity

CPO Oil specific heat


PVT Data Category of Input > FILE …

FILE

Optional statement. Allows you to retrieve data which have been generated in a previous run. You may select only one table from a previous run (i.e., only one source composition). When this statement is used, it is the only statement in the PVT Data Category of input. Refer to your platform Installation Guide for assistance on file management procedures for your operating system and computer hardware.

Mandatory entries: For compositional fluids:

Optional entry:

Example: FILE SETNO=2, PVTFILE=SET01

FILE (for Blackoil)

Optional statement. Each FILE statement allows the simulation to retrieve and use a pre-generated PVT file

Mandatory entries: For compositional fluids:

FILE SETNO=1, PVTFILE=xxx

Example: PVT statement using both SET and GENERATE statements:

PVTDIMENSION MAXDIM=TABL,2/PRES,20/TEMP,10SET SETN=1, GRAV(OIL,API)=35, GRAV(GAS,SPGR)=0.65, * GRAV(WATER)=1.03, FVF=STANDING, SGOR=LASATERGENERATE SETN=1,TYPE=2,PVEC(PSIA)=10,14.7,100,200,300,….., TVEC(F)=50,60,70,….$SET SETN=2, GRAV(OIL,API)=25, GRAV(GAS,SPGR)=0.6, *GRAV(WATER)=1.03, FVF=VAZQUEZ, SGOR=VAZQUEZGENERATE SETN=2,TYPE=2, PVEC(PSIA)=10,14.7,100,200,300,….., TVEC(F)=50,60,70,….

SETNO= The set number which is to be retrieved. This number corresponds to a SETNO entry on a GENERATE statement in a previous run which created the tables. It also is used by the SOURCE statement to identify the table from which properties are to be taken. This entry is not allowed for blackoil calculations.

PVTFILE= The 8 character prefix for the user-specified filename. The file extension is always .PVT and the default is {input file name}.PVT.

SETNO= The PVT set number. For Type=1 PVT table, the set number must match the set number in the Type 1 PVT file.

PVTFILE= The name of the PVT table file. If file cannot be found, an error message will be printed and the program will stop.



STRUCTURE Data Category of Input

Overview

The STRUCTURE Data Category of Input defines the piping system. It is mandatory for all types of simulation.

Table 4-30a: STRUCTURE Data Category of Input


STRUCTURE None p. 75

SOURCE STREAMID= or NAME=, SETNO= or REFSOURCE=, {PRESSURE()= , TEMPERATURE()=, QUALITY=, RATE()=, SET=, ASSAY=LV or COMPOSITION()=, NOCHECK, GOR()=0.0, CGR()=0.0, WCUT=0.0, WGR()=0.0, COEFFICIENT()=, EXP()=, PRIORITY=}

p. 75

CSOURCE STREAMID= or NAME=, SETNO= or REFSOURCE=, {PRESSURE()= , TEMPERATURE()=, RATE()=, SET=, ASSAY=LV or COMPOSITION()=, NOCHECK, PRIORITY=}

p. 78

{WTEST} NAME=, TEMPERATURE()=, PRESSURE()=, RESPRES(), RATE()=, {PI() or VOGEL(), GOR(), WCUT=0.0, GAS, CGR(), WGR()=0.0}

p. 80

{D86 or TBP or D1160 or D2887 or TBP10}

DATA()=percent, temp/percent, temp/ ... p. 81

{API or SPGR or WATSONK}

{DATA()=mid %, value/ mid %, value/...}, AVG= p. 82

{MW} DATA=mid %, value/ mid %, value/..., {AVG=} p. 83

{LIGHTENDS} COMPOSITION()=, RATE= or PERCENT= or FRAC= or MATCH or NOMATCH, STREAM=, NORMALIZE

p. 83

{SINK} {STREAMID= or NAME=}, PRESSURE()=, {TEMPERATURE()=, RATE(), INJECTION, COEFFICIENT()=, EXP()=, SET=}

p. 87

{JUNCTION} STREAMID= or NAME=, {PRESSURE(ESTI)=, TROCK=}, {DETEE or STTEE, ANGLE()=0, {PROPORTIONAL or HONG or ORANJE or TUFFP or CHIEN or SEEUP or SEEHOR or SEEDOWN or USER}

p. 88

{LINK} NAME=, FROM=, TO=, {RATE(ESTI)=, DUAL, INJECT, QMAX()=, QMIN()=0, TOLERANCE(LOWER)=, TOLERANCE(UPPER)=, FWATER, FOIL, FGAS, PRINT}

p. 89


STRUCTURE Data Category of Input > Overview …

{PIPE} {NAME=}, LENGTH()=, {ID()= or NOMD=, SCHEDULE=40, ECHG()=0.0, FCODE=, PALMER=0.924,0.685, ROUGHNESS()=0.0018, ISOTHERMAL or NONISOTHERMAL, WATER or AIR or SOIL, VELOCITY()=10, TAMBIENT()=80, DENSITY()=, VISCOSITY()=, CONDUCTIVITY()=, FLOWEFF=100, HWCOEF()=150, U()=1.0, HINSIDE()=0.0, HOUTSIDE()=0.0, HRADIANT()=0.0, BDTOP()=0.0, THKPIPE()=0.3125, THKINS()=0.0, CONPIPE()=29, CONINS()=0.015, CONSOIL()=0.8, IDSPHERE()=, DELH=, SEGM=}

p. 92

{ANNULUS} {NAME=}, LENGTH()=, {IDAN()=, ODTUBING()=, DEPTH()=, FCODE=, PALMER=0.924,0.685, ROUGHNESS()=0.0018, ISOTHERMAL or NONISOTHERMAL, FLOWEFF=100, HWCOEF()=150, U()=1.0, TGRADIENT()=1.0, DELH=, SEGM=}

p. 94

{TUBING} {NAME=}, LENGTH()=, {ID()= or NOMD=, SCHEDULE=40, DEPTH()=, FCODE=, PALMER=0.924,0.685, ROUGHNESS()=0.0018, ISOTHERMAL or NONISOTHERMAL, FLOWEFF=100, HWCOEF()=150, U()=1.0, TGRADIENT()=1.0, ODTUBING()=, IDCASING()=, ODCASING()=, HOLEID(), CONCASING()=25, EMIS()=0.95, EMOS()=0.95, MEDIUM=, CPANNULUS()=, CONANNULUS()=, BETANNULUS()=, VISANNULUS()=, VELANNULUS()=, DENANNULUS()=, DIFFEARTH=0.96, CONEARTH()=, TIME=, DELH=, SEGM=}

p. 95

{COMPLETION} {NAME=}, JONES or MCLEOD, LENGTH()=, PERFD()=, SHOTS()=, {TUNNEL()=, PERM()=, PENETRATION()=, OVER or UNDER, THICKNESS()=0.5}

p. 101

Table 4-30a: STRUCTURE Data Category of Input (cont.)




Table 4-30b: STRUCTURE Data Category of Input – Equipment Devices (No Length)


{COMPRESSOR} {NAME=}, POWER()= or PRES()= or CURVE()=rate, head, efficiency/rate, head, efficiency/... or CRVn()=rate, head, efficiency/... and RPMC= and RPM= or POWER= or PRESSURE=, {STAGES=1, EFFICIENCY=100}

p. 102

{MCOMPRESS} {NAME=}, POWER()= or PDISCHARGE()= or CURVE()=stage, rate, head, efficiency/stage, rate, head, efficiency/... or PIN()=, {TRAINS=1, STAGES=1, EQUALPR or INTP()=, ADEFF=100, POLY, PEFF=100, PEXP=, INTP()=, INTQ()= or INTT(), INTDP()=, PERCENT()=, NOKCONV, TDIS()=, PRSTAGE()=, STANDARD or ACTUAL}

p. 103

{COOLER} {NAME=}, TOUT()= or DUTY()=, {DP()=0.0, COEFFICIENT=1.0, EXP=1.0}

p. 105

{DPDT} {NAME=}, CURVE()=rate,dp,dt /..., {WELL} p. 105

{EXPANDER} {NAME=}, POWER()= or DP()= or PRATIO= or PRES()=, {EFFICIENCY=100, WTOLERANCE=0.001, TEST()=}

p. 106

{GLVALVE} {NAME=}, RATE()=, {DISSOLVE=100} p. 107

{HEATER} {NAME=}, TOUT()= or DUTY()=, {DP()=0.0, COEFFICIENT=1.0, EXP=1.0}

p. 107

{INJECTION} {NAME=}, FROM=, GAS or COND or WATER or LIQUID, {PRESSURE()= and TEMPERATURE()=, WELL}

p. 108

{IPR} {NAME=}, MODEL= or TYPE=, IVAL=, RVAL=, ARRAY=, {GROUP=}

p. 109

{PUMP} {NAME=}, POWER()= or PRESSURE()= or TYPE=0 and CURVE()=rate,head,efficiency,power/..., or TYPE=0 and HDCONS= and EFFCONS= and PWRCONS= or CRVn()=rate,head,efficiency/... and RPMC= and RPM= or POWER= or PRESSURE=, {STAGES=1, EFFICIENCY=100, AUXILLIARY()=, ALPHA=, DEGRADATION=, SUBMERGENCE()=, CHP()=14.7, PGRAD=0, WELL, LENGTH()=, DEPTH()=,}

p. 119

{REGULATOR} {NAME=}, PRES()= p. 121

{SEPARATOR} {NAME=}, PERCENT()= or RATE()=, {WELL, GIP= or ODPUMP() and IDCASING()=}

p. 122

{EXPANSION} {NAME=}, IDIN()= or NOMID=, IDOUT()= or NOMOD=, {DESCRIPTION=, SCHEDULE=40, ANGLE=180, K=, CHISHOLM or HOMOGENEOUS, LAMBDA=1.0, C2=, USER=, NUMBER=1, COMP}

p. 131

{NOZZLE} {NAME=}, IDPIPE()= or NOMD=, {SCHEDULE=40}, IDNOZZLE()=, {COEFFICIENT=, CPCV=1.4, CHISHOLM or HOMOGENEOUS, LAMBDA=1.0, C2=0.5, USER=, NUMBER=1}

p. 132


STRUCTURE Data Category of Input > Overview …

{ORIFICE} {NAME=}, IDPIPE()= or NOMD=, {SCHEDULE=40}, IDORIFICE()=, {THIN or THICK, COEFFICIENT=, CHISHOLM or HOMOGENEOUS, LAMBDA=1.0, C2=0.5, CPCV=1.4, USER=, NUMBER=1}

p. 133

{TEE} {NAME=}, IDPIPE()= or NOMD=, K= or KMUL=, {DESCRIPTION=, SCHEDULE=40, ROUGHNESS()=0.0018, CHISHOLM or HOMOGENEOUS, LAMBDA=1.0, C2=1.75, USER=, NUMBER=1}

p. 133

{VALVE} {NAME=}, IDIN()= or NOMID=, IDOUT()= or NOMOD=, K= or KMUL=, {DESCRIPTION=, SCHEDULE=40, ANGLE=180, CHISHOLM or HOMOGENEOUS, LAMBDA=1.0,, C2=1.5, VELCON=, USER=, NUMBER=1}

p. 134

{VENTURIMETER} {NAME=}, IDPIPE()= or NOMD=, {SCHEDULE=40}, IDTHROAT()=, {COEFFICIENT=, CPCV=1.4, CHISHOLM or HOMOGENEOUS, LAMBDA=1.0, C2=5.3, USER=, NUMBER=1}

p. 136

Table 4-30c: STRUCTURE Data Category of Input – Fitting Devices


{BEND} {NAME=}, ID()= or NOMD=, K= or KMUL=, {DESCRIPTION=, SCHEDULE=40, STANDARD or NONSTANDARD, RADIUS()=, ANGLE()=, ROUGHNESS()=0.0018, CHISHOLM or HOMOGENEOUS, LAMBDA=1.0, C2=4.35, USER=, NUMBER=1}

p. 124

{CHECK} {NAME=}, ID()=,, {COEFFICIENT=1.0} p. 125

{CHOKE} {NAME=}, ID()=,, FN or UEDA or ORIFICE or PERKINS, {COEF=1.03, CPCV=1.0, WELL}

p. 125

{MCHOKE} {NAME=}, PUPS()= or QRATE ()= or PDOWN()=, {CPCV=1.4, COEF=1.0}

p. 127

{MREGULATOR} {NAME=}, PUPS()= or QRATE ()= or PDOWN()= p. 128

{CONTRACTION} {NAME=}, IDIN()= or NOMID=, IDOUT()= or NOMOD=, {DESCRIPTION=, SCHEDULE=40, ANGLE()=180, K=, HOMOGENEOUS or CHISHOLM, LAMBDA=1.0, C2=0.5, USER=, NUMBER=1}

p. 128

{ENTRANCE} {NAME=}, IDPIPE()= or NOMD=, {DESCRIPTION=, SCHEDULE=40, K=0.5, HOMOGENEOUS or CHISHOLM, LAMBDA=1.0, C2=, USER=, NUMBER=1}

p. 129

{EXIT} {NAME=}, IDPIPE()= or NOMD=, {DESCRIPTION=, SCHEDULE=40, K=1, HOMOGENEOUS or CHISHOLM, LAMBDA=1.0, C2=, USER=, NUMBER=1}

p. 130

Table 4-30b: STRUCTURE Data Category of Input – Equipment Devices (No Length) (cont.)




STRUCTURE



System Nodes

SOURCE

Mandatory statement. Defines a point where fluid enters the system. There may be more than one source in a simulation. The data required depends upon the fluid type. A source may be defined explicitly by giving all its properties, or you may instruct PIPEPHASE that any property not given should be copied from another source.

Mandatory entries: For all fluids:

{EXPANSION} {NAME=}, IDIN()= or NOMID=, IDOUT()= or NOMOD=, {DESCRIPTION=, SCHEDULE=40, ANGLE=180, K=, CHISHOLM or HOMOGENEOUS, LAMBDA=1.0, C2=, USER=, NUMBER=1, COMP}

p. 131

{NOZZLE} {NAME=}, IDPIPE()= or NOMD=, {SCHEDULE=40}, IDNOZZLE()=, {COEFFICIENT=, CPCV=1.4, CHISHOLM or HOMOGENEOUS, LAMBDA=1.0, C2=0.5, USER=, NUMBER=1}

p. 132

{ORIFICE} {NAME=}, IDPIPE()= or NOMD=, {SCHEDULE=40}, IDORIFICE()=, {THIN or THICK, COEFFICIENT=, CHISHOLM or HOMOGENEOUS, LAMBDA=1.0, C2=0.5, CPCV=1.4, USER=, NUMBER=1}

p. 133

{TEE} {NAME=}, IDPIPE()= or NOMD=, K= or KMUL=, {DESCRIPTION=, SCHEDULE=40, ROUGHNESS()=0.0018, CHISHOLM or HOMOGENEOUS, LAMBDA=1.0, C2=1.75, USER=, NUMBER=1}

p. 133

{VALVE} {NAME=}, IDIN()= or NOMID=, IDOUT()= or NOMOD=, K= or KMUL=, {DESCRIPTION=, SCHEDULE=40, ANGLE=180, CHISHOLM or HOMOGENEOUS, LAMBDA=1.0,, C2=1.5, VELCON=, USER=, NUMBER=1}

p. 134

{VENTURIMETER} {NAME=}, IDPIPE()= or NOMD=, {SCHEDULE=40}, IDTHROAT()=, {COEFFICIENT=, CPCV=1.4, CHISHOLM or HOMOGENEOUS, LAMBDA=1.0, C2=5.3, USER=, NUMBER=1}

p. 136

STREAMID= or

Identifies the source. Up to twelve alphanumeric characters.

NAME= Identifies the source. Up to twelve alphanumeric characters.

Table 4-30c: STRUCTURE Data Category of Input – Fitting Devices (cont.)



STRUCTURE Data Category of Input > SOURCE …

Other entries for all fluids:

Other entries for Compositional Sources:

SETNO= or REFSOURCE=

Use one of these. SETNO must be numeric. It is the identifier which links the source to a set of properties defined in the PVT data category. When you use REFSOURCE, the temperature, pressure, rate and composition of the referenced source are copied into this source. You can then override any one or more of these using entries on this statement.

PRESSURE()= Mandatory entry unless REFSOURCE is used. Use the ESTI qualifier if the pressure is estimated

For time-stepping, if the source drains a reservoir, the source pressure is interpreted as the reservoir pressure at the source location at time = 0.0. This pressure may be different from the average reservoir pressure. This pressure difference is maintained throughout the time-stepping.

TEMPERATURE()= Mandatory entry, unless REFSOURCE is used or, for a steam or single component source, QUALITY is given. For single component source QUALITY must be specified. If QUALITY=0 or 100%, then TEMPERATURE must also be specified.

RATE()= Mandatory entry unless REFSOURCE is used or unless compositional rates are specified. Use the ESTI qualifier if the rate is estimated. The units in which you must express the flowrate of a non-compositional fluid depends on the fluid type: Fluid Type Rate Basis Non-compositional gas Gas volume unitsNon-compositional liquid Liquid volume unitsSteam Weight units

For a compositional fluid, you may also use a qualifier to define the basis of the flowrate. Options are: LV, GV, W, or M for liquid volume, gas volume, weight, or moles. The default basis is moles, except for ASSAY.

PRIORITY= Integer that indicates the priority of shut in for the source under the various well control options. For example if there are two sources, and the priority of one is 1 and the priority of the other is 2, then PIPEPHASE will first preferentially shut the source with PRIORITY=1.

SET= Identifies the thermodynamic set name as defined in the Thermodynamic Data Category. The defined thermodynamic set will then be used for the link associated with this source.

ASSAY=LV Use this with Compositional sources. ASSAY instructs PIPEPHASE to expect source data in the form of an assay curve (see below). You must define the basis of the assay. Options are LV and WT. Cannot be used with COMPOSITION.

or



Other entries for Blackoil Sources:

Other entries for Gas Condensate Sources:

Other entries for Single Phase Gas Sources:

Other entries for Steam Sources and Single Component Sources:

Other entries for GUI PFD Layout:

Example: SOURCE NAME=FEED, SETNO=1, PRES=0, TEMP(C)=40, RATE=100SOURCE NAME=13, PRESS=125, TEMP=136, RATE(W)=2000,& COMP=0.8/0.1/0.05/0.05

COMPOSITION()= The component breakdown of the SOURCE in fractions, percents, or rates. Cannot be used with ASSAY. Basis may be:

M Moles (Default) W Weight LV Standard liquid volume GV Standard gas volume

Format for data entry is: COMPOSITION(basis) = i, value/...

Component rates which sum to 1.0 or 100.0 are taken as fractions or percents respectively. For other totals, the sum is taken as the total rate and checked against the RATE entry. If the total rate and the RATE entry do not agree, an error is signalled unless the NOCHECK keyword is also used. For NOCHECK, component rates are normalized to agree with RATE.

NOCHECK Use this keyword with COMPOSITION to request normalization of component percentages or fractions. Unless NOCHECK is invoked, COMPOSITION must sum to 1.0, 100.0 or the value defined on the RATE entry.

GOR()=0.0 Optional entry. Gas-oil ratio.

WCUT=0.0 Optional entry. Volume percent of water in the liquid phase.

CGR()=0.0 Optional entry. Condensate gas ratio .

WGR()=0.0 Optional entry. Water gas ratio.

COEFFICIENT()= and EXP()=I

Optional entries. Define the Inflow Performance Relationship of a well source using the gas flow equation. See IPR device for alternate specification.

COEFFICIENT()= and EXP()=

Optional entries. Define the Inflow Performance Relationship of a well source using the gas flow equation.

QUALITY= Use instead of or in addition to TEMPERATURE. QUALITY must be between 0 and 100 percent. If quality is given, PIPEPHASE calculates the corresponding temperature at the given pressure. If quality is specified as zero or 100 percent, the temperature must also be supplied.

XCOR = xxxYCOR = xxx

GUI Coordinates to place the icon on the PFD.The user should not change this data.


STRUCTURE Data Category of Input > CSOURCE …

SOURCE NAME=12, PRESS=115,& RATE(W)=1000, TEMPERATURE=136, REFS=13SOURCE NAME=W, RATE=70000, PRES(ESTI)=170, QUALITY=98SOURCE NAME=FEED, SETNO=1, PRES=114, RATE(W)=1500000, & TEMPERATURE=60, ASSAY=LV SOURCE NAME=100, TEMP=150, PRES=1000, & COMP=1,3000/2,35/3,30/4,890/5,300/6,520/7,105/8,283/& 9,100/10,133/11,165/12,303/13,560/14,930/15,300/& 16,300/17,300/18,280/19,260, RATE=8800, NOCHECK, SET=THERMO1

CSOURCE

Mandatory statement for compositionally-defined sources for the compositional blackoil model. Defines a point where fluid enters the system. There may be more than one source in a simulation. All the statements that define a source must be grouped together. The data required depends upon the fluid type. A source may be defined explicitly by giving all its properties, or you may instruct PIPEPHASE that any property not given should be copied from another source.


Other entries for all fluids:

STREAMID=or

Identifies the source. Up to twelve alphanumeric characters.

NAME= Identifies the source. Up to twelve alphanumeric characters.

SETNO= orREFSOURCE=

Use one of these. SETNO must be numeric. It is the identifier which links the source to a set of properties defined in the PVT data category. When you use REFSOURCE, the temperature, pressure, rate and composition of the referenced source are copied into this source. You can then override any one or more of these using entries on this statement.

PRESSURE()= Mandatory entry unless REFSOURCE is used. Use the ESTI qualifier if the pressure is estimated.

For time-stepping, if the source drains a reservoir, the source pressure is interpreted as the reservoir pressure at the source location at time = 0.0. This pressure may be different from the average reservoir pressure. This pressure difference is maintained throughout the time-stepping.

TEMPERATURE()= Mandatory entry, unless REFSOURCE is used or, for a steam or single component source, QUALITY is given. For single component source QUALITY must be specified. If QUALITY=0 or 100%, then TEMPERATURE must also be specified.



Other entries for Compositional Sources:

Example:CSOURC NAME=1,RATE=100,TEMP=140,PRES(ESTI)=100, & COMP=20/40/40,NOCHECK, SETNO=2NAME=2,RATE=100,TEMP=100,PRES=89,REFSOURCE=2,SETNO=2

RATE()= Mandatory entry unless REFSOURCE is used or unless compositional rates are specified. Use the ESTI qualifier if the rate is estimated. The units in which you must express the flowrate of a non-compositional fluid depends on the fluid type: Fluid Type Rate Basis Non-compositional gas Gas volume units Non-compositional liquid Liquid volume unitsSteam Weight units

For a compositional fluid, you may also use a qualifier to define the basis of the flowrate. Options are: LV, GV, W, or M for liquid volume, gas volume, weight, or moles. The default basis is moles, except for ASSAY.

PRIORITY= Integer that indicates the priority of shut in for the source under the various well control options. For example if there are two sources, and the priority of one is 1 and the priority of the other is 2, then PIPEPHASE will first preferentially shut the source with PRIORITY=1.

SET= Identifies the thermodynamic set name as defined in the Thermodynamic Data Category. The defined thermodynamic set will then be used for the link associated with this source.

ASSAY=LV Use this with Compositional sources. ASSAY instructs PIPEPHASE to expect source data in the form of an assay curve (see below). You must define the basis of the assay. Options are LV and WT. Cannot be used with COMPOSITION.

COMPOSITION()= The component breakdown of the SOURCE in fractions, percents, or rates. Cannot be used with ASSAY. Basis may be:

M Moles (Default) W Weight LV Standard liquid volume GV Standard gas volume

Format for data entry is: COMPOSITION(basis) = i, value/...

Component rates which sum to 1.0 or 100.0 are taken as fractions or percents respectively. For other totals, the sum is taken as the total rate and checked against the RATE entry. If the total rate and the RATE entry do not agree, an error is signalled unless the NOCHECK keyword is also used. For NOCHECK, component rates are normalized to agree with RATE.

NOCHECK Use this keyword with COMPOSITION to request normalization of component percentages or fractions. Unless NOCHECK is invoked, COMPOSITION must sum to 1.0, 100.0 or the value defined on the RATE entry.


STRUCTURE Data Category of Input > WTEST …

WTEST

Optional statement. Defines the Inflow Performance Relationship of a well from measured data. This statement may be used only in a SINGLE link calculation. It must follow immediately after the SOURCE statement to which it refers.

This statement is used with Blackoil, Condensate, Liquid or Gas. The data required depends upon the fluid type.


Other entries for Blackoil:

Other entries for Gas Condensate:

Other entries for Single-phase Liquid:

Other entries for Single-phase Gas:

NAME= Identifies the test device at the outlet of which the test measurements were taken. Up to four alphanumeric characters.

TEMPERATURE()= Measured temperature at the test device outlet. For a gas or condensate run two data entries must be supplied for the two test rates.

PRESSURE()= Measured pressure at the test device outlet. For a gas or condensate run two data entries must be supplied for the two test rates.

RESPRES()= Reservoir pressure at the time the measurements were taken. For a gas or condensate run two data entries must be supplied for the two test rates.

PI()= or VOGEL()=

Mandatory entry. Defines the IPR of a well source by Productivity Index or the Vogel equation.

RATE()= Mandatory entry. Measured standard volume oil flowrate.

GOR()= Mandatory entry. Formation gas-oil ratio measured at testing conditions.

WCUT=0.0 Optional entry. Volume percent of water in the liquid phase.

GAS Mandatory entry. Specify that the gas flow equation is to be used.

RATE()= Mandatory entry. Testing gas volumetric flowrate. Two data points must be supplied

CGR()=0.0, 0.0 Optional entry. Condensate gas ratio.If entered, two data points must be supplied.

WGR()=0.0, 0.0 Optional entry. Water gas ratio. If entered, two data points must be supplied.

PI()= or VOGEL()=

Mandatory entry. Defines the IPR of a well source by Productivity Index or the Vogel equation.

RATE()= Mandatory entry. Measured liquid flowrate.

GAS Mandatory entry. Specify that the gas flow equation is to be used.



Distillation Data

This statement is necessary only if Assay curve is used. One of the following statements must appear immediately after the corresponding SOURCE statement and prior to the next SOURCE statement or THERMO statement. It supplies the distillation data for the fluid portion of the stream. Solids are not considered in the distillation data. The DATA entry is required; all other entries are optional.

The FIT option on the ASSAY statement in the Component Data Category determines the curve fitting procedure used to process the distillation data. The default cubic SPLINE method requires a minimum of 2 data points. When only two data points are present, PIPEPHASE uses a probability density function to fill in the remainder of the curve. All other fitting procedures require 3 data points for TBP curves, and 5 points for other distillation data.

By default, PIPEPHASE assumes a pressure of 760 mmHg for the supplied data. For all distillation data options except D2887, the PRES option allows changing the pressure at which the data were taken or to which the data were corrected.

RATE()= Mandatory entry. Testing gas volumetric flowrate. Two data points must be supplied.

D86 DATA= pct, value / pct, value / ..., {TEMP= K or C or R or F, STREAM=sid, PRES(MMHG)=760.0, CRACKING}

or

TBP or D1160

DATA= pct, value / pct, value/ ..., {TEMP= K or C or R or F, STREAM=sid, PRES(MMHG)= 760.0}

or

D2887 DATA= pct, value / pct, value / ..., {TEMP= K or C or R or F, STREAM= sid}

D86

or

This statement supplies ASTM D86 distillation data, normally taken at atmospheric pressure (760 mmHg). Use the PRES entry to correct for data measured at another pressure. Use the CRACKING entry (below) to correct for thermal cracking.

TBP or

Supply true boiling point distillation data on this statement, using the PRES entry to indicate the pressure at which the data were measured.

D1160

or

This statement supplies ASTM D1160 distillation data, normally measured in partial vacuum conditions. By default, data is corrected to 1 atmosphere (760 torr). Use the PRES entry to correct data to another pressure.

D2887 This statement allows entry of data that describes a distillation curve simulated in accordance with the ASTM D2887 procedure.

Note: No pressure entry appears on this statement.


STRUCTURE Data Category of Input > Gravity Data …

Gravity Data

Standard liquid gravity measured at 60oF (15.5oC).

One of these statements must follow the distillation data statement after the SOURCE statement. These statements offer alternative forms for defining the liquid density of the assay at 60oF (15.5oC). The AVERAGE entry is required; all other entries are optional. When the DATA entry is not supplied, PIPEPHASE generates a gravity curve based on the distillation data and the average gravity value.

DATA This entry is required to supply the actual distillation data points. Each data point consists of two pieces of information: (1) the cut point, expressed as a percentage of the cumulative distillates and (2) the temperature of the cut. Data must appear with the cut percentages in ascending order, consistent with the basis declared on the ASSAY entry of the SOURCE statement. Any data supplied on the LIGHTENDS statement override the corresponding portion of the distillation data.

TEMP This optional entry identifies the dimensional unit used to supply temperature data. If omitted, the temperature unit declared on the DIMENSION statement in the General Data Category serves as the default. Available arguments include C (Celsius), K (Kelvin), F (Fahrenheit), or R (Rankine) degrees.

PRES The PRES entry allows specifying the pressure at which the distillation data were measured, or to which the data are corrected. The default pressure is 760 mmHg. The default dimensional unit is the problem pressure unit.

STREAM This supplies a stream label. It is optional; but when used, it must agree with the stream label declared on the SOURCE statement, or an input error occurs.

CRACKING Presence of this keyword corrects D86 data for the effects of thermal cracking. It is available only on the D86 statement.

Note: This correlation was removed from the API Data Book in 1987, but remains available as an option to provide consistency for older data.

API or SPGR or WATSONK

AVERAGE= value, {STREAM= sid}, {DATA= pct, value / pct, value / pct, value / ...}

API API gravity.

SPGR Specific gravity.

WATSONK Watson (or UOP) characterization factor data.

AVERAGE This entry defines the average value for the fluid portion of the stream, including any lightends. Solid components are not considered. This entry is required.



Molecular Weight

The following optional statement defines the molecular weight curve for the assay stream.

If this statement is used, the DATA entry must appear, but the AVERAGE and STREAM entries always are optional. If the MW statement is not given, PIPEPHASE estimates the molecular weights for all assay cuts, using the method chosen by the MW entry on the ASSAY statement, in the Component Data Category of input.

LIGHTENDS

The LIGHTENDS statement defines the light hydrocarbon components in the assay analysis.

DATA This option allows entry of user-supplied data points that replace the PIPEPHASE generated gravity curve. If used, at least three data points must be provided, consistent with the basis declared on the ASSAY entry of the SOURCE statement. pct Mid-volume percent or mid-weight percent of the data point.value The gravity or Watson characterization value of the point

associated with the pct argument.

STREAM Stream label. It is optional, but when used, must agree with the stream label declared on the SOURCE statement, or an input error occurs.

MW DATA= pct, value / pct, value / pct, value / ..., {AVERAGE= value, STREAM= sid}

DATA The data entry must define at least three points that appear in the order of ascending weight percentages. An unlimited number of points may be supplied. pct Mid-volume percent or mid-weight percent of the data point.value The gravity or Watson characterization value of the point

associated with the pct argument.

AVERAGE Optionally, this defines the average molecular weight of the fluid portion of the stream. Solid components are ignored. If AVERAGE is given, PIPEPHASE normalizes or extrapolates the molecular weight curve, as required to satisfy the average molecular weight of the stream. If omitted, PIPEPHASE uses quadratic extrapolation of the molecular weight curve, as needed, to compute an average molecular weight.

STREAM Stream label. It is optional, but when used, must agree with the stream label declared on the SOURCE statement, or an input error occurs.

LIGHTENDS COMPOSITION(M or WT or LV or GV)= i, value / ...,{RATE(M or WT or LV or GV)= value orFRACTION(WT or LV)= value or PERCENT(WT or LV)= value or MATCH or NOMATCH},{STREAM= sid, NORMALIZE}


STRUCTURE Data Category of Input > LIGHTENDS …

All components appearing on this statement must be defined in the Component Data Category. The COMPOSITION entry is required, but all other entries are optional.

In the following figure, point a is the midpoint volume percent of the highest boiling pure component. This cumulative percentage point is adjusted to intercept the TBP curve. Point b is the volume percent of the total lightends.

COMPOSITION Required. This entry identifies the components that constitute the lightends of the stream. The flow of each component in the lightends may be supplied as an actual flow rate or as a fraction or percentage of the total stream fluid rate. Solids are not included. The basis may be mole (M), weight (WT), liquid volume (LV), or gas volume (GV) and may be different from the basis used on the RATE, FRACTION, or PERCENT entry. If i is omitted, it defaults to the next component number in sequence. If none of the i arguments are given, then the first value is associated with component 1.

If RATE, PERCENT, or FRACTION is given:

The value given is the composition for each component i. The sum of the values must equal 1.0 0.01, 100 1 or the desired rate 1%. Alternatively, the NORMALIZE keyword may be used to adjust the values to the desired rate.

If MATCH is given:

The values are adjusted by a constant factor so that the lightends flowrate matches the low-boiling portion of the TBP curve.

If RATE, PERCENT, FRACTION or MATCH is not given:

The values are the actual flowing amounts.

RATE Optional. If used, this entry defines the total lightends rate on a mole (M), weight (WT), liquid volume (LV), or gas volume (GV) basis. The basis may be different from the COMPOSITION basis.

or

FRACTION or PERCENT

Optional. This defines the total lightends rate as a fraction or percent of the total stream fluid rate. The basis may be either weight (WT) or liquid volume (LV). The basis may be different from the COMPOSITION basis. The default basis is set by the ASSAY entry on the SOURCE statement.

or

MATCH or NOMATCH

The MATCH option adjusts the lightends flow rate to match the TBP curve, as shown in Figure 4-1. The adjustment ensures the mid-volume percentage of the highest boiling lightend component (that is available in significant quantity) and intercepts the TBP temperature curve at the specified volume percent. This is the default. The NOMATCH option does not adjust the lightends flow rate to match the TBP curve.



Figure 4-1: Lightends Matching

Optional entries: NoneMandatory entries: NoneExample: Composition and rate given:LIGHTEND STREAM=1, COMP=1./2./3./4.0, RATE= 10.0

Composition given and rate defined as a fraction or percent of the RATE entry given on the SOURCE statement:

LIGHT STREAM=1, COMP(WT)= 0.1/0.2/0.3/0.4, FRAC(V)= 0.02 LIGHT STREAM=1, COMP= 10./ 20./ 30./ 40., PERCENT= 2.0Match lightend flowrate to intercept the TBP curve:LIGHTEND STREAM=1, COMP= 1.0 / 2.0 / 3.0 / 4.0, MATCHCOMP entries as actual flowing values:LIGHTEND STREAM= 1, COMP(V)= 1.0/2.0/3.0/4.0

STREAM Stream label. It is optional, but when used, it must agree with the stream label declared on the SOURCE statement, or an input error occurs.

NORMALIZE Optional. When RATE, FRACTION, or PERCENT is present, the NORMALIZE option normalizes the total rate of the lightends to obtain the required rate, regardless of the sum of the values supplied for the COMPOSITION entry.


STRUCTURE Data Category of Input > LIGHTENDS …

Example: SOURCES with Assay Data. Set up SOURCES input for the following three streams:

PROPERTYSTREAM= 1, TEMP= 150.0, PRES= 50.0, & RATE(LV)= 1200.0, PHASE= L, ASSAY= LVD86STREAM= 1, DATA= 0.0, 100./ 10., 210./ & 30., 240./ 50., 260./ 70., 275./ 90., 290./ 100., 310.APIAVERAGE= 60.0, STREAM= 1LIGHTENDS STREAM= 1, RATE= 50.0, & COMPOSITION= 1, 2./ 2, 10./ 3, 28./ 4, 7./ 5, 3.0PROPERTYSTREAM= 2, TEMP= 100.0, PRES= 50.0, & RATE(2)= 1500.0, PHASE= L, ASSAY= LV

Stream Label

1 2 V6

Assay BasisDistillation Type

LV ASTM D86

LVASTM D1160

WTTBP

IBP 10% 30% 50% 70% 90% EP

100210240260275290310

310360385410560 -- --

201 --

370390 --

450 --

Gravity type API Watson K SpGr

Stream averageMid % 25

37 52

60 -- -- --

12.5------

0.760.310.420.65

Lightends

Total flow Comp. no.

12345

50 moles -- 2

10 28 7 3

-- -- -- -- -- -- --

11% by weight-- 8.0

12.0 31.0 42.0 7.0

Thermalconditions

TemperaturePressure

Phase

15050

Liquid

10050

Liquid

20075

Mixed

Total rate, basis 1200, LV 1500, LV 2700, WT



D1160STREAM= 2, DATA= 0.00, 310./ 10., 360./ 30., 385./ & 50.0, 410.0 / 70.0, 560.0WATSONKAVERAGE= 12.5, STREAM= 2PROPERTYSTREAM= V6, TEMP= 200.0, PRES= 75.0, & RATE(W)= 2700.0, PHASE= M, ASSAY= WTTBP STREAM= V6, DATA= 0.0, 201./ 30.0, 370.0/ & 50.0, 390.0 / 90.0, 450.0SPGRSTREAM= V6, AVERAGE= 0.76, & DATA= 25.0, 0.31 / 37.0, 0.42 / 52.0, 0.65LIGHTENDSTREAM= V6, PERCENT(WT)= 11.0, & COMP(W)= 1, 8.0 / 2, 12.0 / 3, 31.0 / 4, 42.0 / 5, 7.0

SINK

Defines a point where fluid leaves the system. You may have more than one sink in a network simulation. As demonstrated in the following table, the requirements for entries for this statement depend on the type of simulation.

Table 4-31: Mandatory Entries for SINK

Conditional entries:

Simulation Type Mandatory Sink Data

Network Stream ID or Name. Estimated or fixed pressure. Estimated or fixed rate.

STREAMID=or

Identifies the sink. Up to twelve alphanumeric characters.

NAME= Up to twelve alphanumeric characters.

PRESSURE()= Pressure at the sink. Use the ESTI qualifier if the value is an estimated one.

TEMPERATURE()= Fixed temperature at the sink.

RATE()= Rate of outflow at the sink. Use the ESTI qualifier if the value is an estimated one. The basis of the rate must conform to the following rules dependent on the fluid type:Fluid Type Rate Basis Non-compositional gas Gas volume units Non-compositional liquid Liquid volume unitsSteam Weight unitsCompositional fluid Weight units

For the Blackoil model the user has the additional ability to specify the standard volumetric flowrates of either gas, oil, water or liquid at the sink. The default basis is the combined liquid flow of oil and water at the sink. The user can also specify the unit basis of the standard volumetric flowrate.


STRUCTURE Data Category of Input > JUNCTION …

Optional entries:

Other entries for GUI PFD Layout:;

Example:

SINK NAME=FLRB, PRESSURE=21, RATE(ESTI)=140

JUNCTION

Mandatory statement for the network calculation method, where two or more links connect.

Mandatory entries for all network simulations:

Optional entries for all network simulations:

For the Compositional model the user has the ability to specify in addition to the total mass rate of flow at the sink the standard volumetric flowrate of either gas/oil or water at the sink with appropriate volume qualifiers. The default basis is the mass flow at the sink. However, to specify the mass rate with unit qualifiers, the user must specify that the basis is weight (WT), thus the following is appropriate syntax:

RATE(wt,weight units)=

In addition the qualifiers, WATER/GAS/OIL are now used to allow the user to specify the volumetric flows of the respective phases at the sink.

INJECTION Optional entry. Use this keyword to specify an injection well.

COEFFICIENT()= and EXP()=

Optional entries to define the injectivity of a well using the gas flow equation. Can be used only for Single-Phase Gas or Gas Condensate.

II()= Optimal entries to define the injectivity index for all fluid types.

SET= Identifies the thermodynamic set name as defined in the Thermodynamic Data Category. The defined thermodynamic set will then be used for the fluid at the sink node.



STREAMID=or

Identifies the sink. Up to twelve alphanumeric characters.

NAME= Identifies the junction. Up to twelve alphanumeric characters.

PRESSURE(ESTI)= Estimate of pressure at this junction. The qualifier ESTI must be used. If you supply a pressure estimate, it should be consistent with the estimated direction of flow.



Optional entry for Compositional Systems only:

Optional entries for modeling preferential splitting at a tee junction, for Steam Systems only:


Example:

JUNCTION NAME=A, PRESSURE(ESTI)=165, DETEE, ORANJE

LINK

Mandatory for network simulations. Defines a series of devices (flow devices, fittings and items of process equipment). The statements defining these devices must appear immediately after the LINK statement. Flow is assumed to be from one item to the next, in the order in which they appear in the input and in the direction designated by the FROM and TO entries.

Mandatory entries:

TROCK()= Temperature of the rock formation at this junction. Required entry for subsurface junctions and the first surface junction.

SET= Identifies the thermodynamic set name as defined in the Thermodynamic Data Category of input. The defined thermodynamic set will then be used for the fluid at the junction node.

DETEE or STTEE

Junction is a dead-end tee or a straight-through tee.

Note: The smaller diameter pipe leaving the junction is always considered the branch link.

ANGLE()=0 Angle of branch. Limits are 90 degrees for vertical incline; –90 degrees for vertical decline.

PROPORTIONAL orHONG orORANJE orTUFFP orCHIEN orSEEUP orSEEHOR orSEEDOWN orUSER

Select a method for calculating phase splitting at the junction. HONG or TUFFP may be used with ANGLE if the branch is not horizontal. Use a user-defined model to calculate phase splitting at this junction. When you use this entry, you must have an additional PSPLIT category of data at the end of the simulation input. See the PSPLIT Data Category of input near the end of this chapter for further details. See References (99-104) for more information on these preferential phase split models.



NAME= Identifies the link. Up to four alphanumeric characters. When using gaslift, the name of the production string must be PROD and the name of the injection string must be GASL.


STRUCTURE Data Category of Input > LINK …

Optional entries:

Note: In a network, there may be more than one feasible link calculation sequence. In PIPEPHASE the links are first ordered alphanumerically before the feasible ordering is done. This guarantees that the same calculation sequence is arrived at no matter what the link input order was in the keyword file. However if the link name is changed the program may arrive at an alternate feasible link calculation sequence

FROM=, or F= Identifies the source or junction where this link starts. Up to twelve alphanumeric characters.

TO=, or T= Identifies the sink or junction where this link ends. Up to twelve alphanumeric characters.

RATE(ESTI)= Estimate of the flowrate through this link. The qualifier ESTI must be used. If a rate estimate is supplied for one link, an estimate must be supplied for all links. Otherwise PIPEPHASE will generate its own estimates and ignore those estimates supplied. The handling of user supplied estimate differs based on the flow allocation method. For most methods, the simulator will provide initial estimates which are overridden by the user estimates. The FLOWALLOC=1 or FLOWALLOC=2 keywords (see the previous section on Network Data Category of input) may be used to enable the mixing of user-supplied and program-generated link flowrate estimates. In this case the user estimates will be taken into account, but conflicting estimates will be adjusted to be as close to the user estimates as possible. When using a restart file, the restart file estimates are taken as the highest priority and user supplied estimates for a given link will be used only if no data is available in the restart file.

DUAL= For detailed heat transfer in dual completions. Specify the name of the link that forms a dual completion with this link. Valid for Network calculations with Blackoil, steam and compositional fluids. Only concentric completions are allowed with compositional fluids. The detailed heat transfer data are entered on the TUBING statement in the Structure Data Category of input.

INJECT To specify that a link is an injection well. Mandatory when modeling subsurface networks with multiple completion zones in injection wells.

QMAX()= Enter the maximum flowrate to be allowed through the link. This maximum flow constraint will be activated only if the following four conditions are all met:1 The flowrate is not fixed in the link.2 The link is a source link with the source pressure fixed and the flowrate

is unknown.3 There is at least one surface regulator with the pressure set to a value

higher than the system pressure (e.g., 99999 psia)4 The regulator is not the last device in the link.

Note: If the flow exceeds QMAX beyond the upper tolerance, PIPEPHASE calculates the regulator pressure that needs to be set in order to meet the maximum flow constraint specified.




Example:

LINK NAME=J, F=13, TO=JTK, RATE(ESTI)=1.E6, PRINT

Two other conditions can also invoke the QMAX logic:2b The link is not a source link and the link flowrate is not fixed explicitly

(e.g., a sink link with the sink rate fixed will fix the link flowrate) or implicitly (e.g., spur links have fixed flowrates).

3b The link has at least one choke or valve in the link. In this case PIPEPHASE will keep the flow between the upper and lower tolerance values.

Note: PIPEPHASE varies the choke or valve size as part of the network iterations to keep the flow below the maximum within tolerance.

If 1 and 3b are not both true, then the maximum flow logic will be inactivated.

If 1 and 3b are true and 2b is not true, the network will fail to converge.

QMIN()=0 Enter the minimum flowrate to be allowed through the link. If the flowrate falls below this value, the PBAL convergence algorithm will shut down the link. This logic can be used to simulate well shutdown when the well production falls below some minimum flowrate.

TOLERANCE(LOWER)= Specifies the lower flow tolerances as a fraction of the QMAX value.

TOLERANCE(UPPER)= Specifies the upper flow tolerances as a fraction of the QMAX value.

FGAS Desired gas volume fraction (in percent) of link flow.

FWAT Desired water volume fraction (in percent) of link flow.

FOIL Desired oil volume fraction (in percent) of link flow.

The purpose of the FGAS/FWAT/FOIL options is to allow the user to control the volume fractions of fluids in a link. The FGAS, FOIL and FWAT options can only be used with the mass based formulation of the blackoil model.

Note: The quantities FOIL, FWAT and FGAS can only be specified once for any and all links that emanate from a given node. Thus, if three links carry flow from a node, then FWAT/FGAS/FOIL can be specified for, at most, one of the three links.

PRINT Use this entry to generate a detailed report for the link. This detailed report will include a phase envelope plot if the PLOT=FULL and DEVICE=PART or FULL options have both been specified on the PRINT statement in the General Data Category of input. If the PRINT option is not specified on any link and DEVICE=PART or FULL is in the PRINT statement, detailed reports will be generated for every link in the simulation. Therefore it is recommended that you use this keyword to select only those links of interest.


GUI Coordinates to position the link on the PFD. If no information is given, a direct connection is given between the attached nodes.The user should not change this data.


STRUCTURE Data Category of Input > Flow Devices (have length) …

Flow Devices (have length)

PIPE

Any value defined on any pipe statement will override the corresponding values set globally in the General Data Category of input.

Mandatory entries:

Optional entries:

LENGTH()= Pipe length in long length units.

NAME= Identifies the pipe. Used for cross-referencing. Up to four alphanumeric characters.

ID()= or NOMD= Inside diameter of pipe in short length units. Nominal inside diameter of pipes (in inches only).

Note: If neither of these keywords is specified on the PIPE statement, either IDPIPE or NOMD must have been specified as a General Default.

SCHEDULE=40 Pipe schedule.

Note: If a nominal diameter is not available for a user-defined schedule in the selected table, then PIPEPHASE will generate an error message. If the schedule is not defined, then the default schedule 40 is used. If a match cannot be found, PIPEPHASE will produce an error message.

ECHG()=0.0 Elevation change from inlet to outlet. Positive is uphill.

FCODE= Defines pressure drop and holdup method. Select a code from Table 4-6a or Table 4-6b.

PALMER=0.924,0.6851 Use Palmer liquid holdup correction factors. Two values must be supplied: uphill and downhill. The defaults shown apply only to BB or BBM correlations; if the default values are to be used, only include the PALMER keyword without any values. If different values are required, supply those values with the PALMER keyword. If you are using any other correlation, you must supply values with the PALMER keyword. If you want to correct only downhill holdup, supply a value of 1.0 for the uphill correction factor.

ROUGHNESS()=0.0018 Pipe inside roughness in short length (special) units (see Table 4-4). Use the qualifier REL to denote roughness as a fraction of the pipe inside diameter.

ISOTHERMAL orNONISOTHERMAL

Use ISOTHERMAL to suppress heat balance calculations. Use NONISOTHERMAL to override an ISOTHERMAL entry on the CALCULATION statement in the General Data Category of input and thus reinstate heat balance calculations.

WATER or AIR or SOIL

Use one of these to specify the medium surrounding the pipe.



VELOCITY()=10 Velocity of the surrounding air or water.

TAMBIENT()=80 Ambient temperature of the surrounding medium.

DENSITY()= Density of the surrounding air or water. Defaults are specific gravity of 1.0 for air and 10.0 API for water.

VISCOSITY()= Viscosity of the surrounding air or water. Defaults are 0.02 cP for air and 1.0 cP for water.

CONDUCTIVITY()= Thermal conductivity of the surrounding air, water, or soil. Defaults are 0.015 BTU/hr-ft-oF for air, 0.3 BTU/hr-ft-oF for water and 0.08 BTU/hr-ft-oF for soil.

FLOWEFF=100 Flow efficiency as a percentage. This parameter may be used in a rating exercise to adjust flowrates to meet a measured pressure drop. The use of FLOWEFF is recommended only when other parameters, such as pressure drop method, pipe roughness, heat transfer coefficient Heat transfer coefficientvalues, etc. have been varied in order to match field data.

HWCOEFF()=150 Hazen-Williams coefficient, for use with the Hazen-Williams pressure drop method for single-phase liquids.

U()=1.0 Overall heat transfer coefficient from inside a pipe to the surroundings.

HINSIDE()=0.0 Additional heat transfer coefficient which will be added to the inside film heat transfer coefficient calculated by PIPEPHASE.

HOUTSIDE()=0.0 Additional heat transfer coefficient which will be added to the outside film heat transfer coefficient calculated by PIPEPHASE.

HRADIANT()=0.0 Additional radiant heat transfer coefficient which will be added to the outside film heat transfer coefficient calculated by PIPEPHASE.

BDTOP()=0.0 Depth of a buried pipe measured from the top of the outside of the pipe, in short length units.

Note: To define data for a partially buried pipe:

1 Define the surroundings as AIR or WATER only (not SOIL). 2 Specify a negative BDTOP. BDTOP is the distance from the surface of the soil to the top of the pipe

outermost diameter. The magnitude of the negative burial depth however makes sense only if it is less than the outermost diameter of the pipe (including the insulation thickness if any).

3 If desired, specify the value of CONSOIL (the conductivity of the soil). In this case PIPEPHASE will do an internal calculation for the heat transfer coefficient for the buried portion of the pipe. The default value of CONSOIL will be used.

4 Additionally, if you wish to override PIPEPHASE’s internal soil heat transfer coefficient calculation you may specify the HOUTSIDE keyword and value for the soil portion of the pipe. The use of the HOUTSIDE keyword will override the method described in (3).

THKPIPE()=0.3125 Pipe thickness in short length units.

THKINS()=0.0 Insulation thickness in short length units.

CONPIPE()=29 CONINS()=0.015 CONSOIL()=0.8

Thermal conductivity of the pipe material, insulation and soil.

IDSPHERE()= Diameter of the sphere used for pigging in short length units.


STRUCTURE Data Category of Input > ANNULUS …

Example:PIPE NAME=PIP1, LENGTH=30, ID=3.068PIPE ID=3, LENGTH=5808, ECHG=140, U=0.0001PIPE NAME=A-J, ID=8, LENGTH=170, & WATER, VISCOSITY(CP)=1.5, VELOCITY=5, DENSITY(LBFT3)=68,& COND=0.33, TAMB=5, CONPIPE=35, THKPIPE=0.8, THKINS=5PIPE NAME=X1, NOMD=3, SCHE=30

ANNULUS

Define a well annulus. Any value defined on an Annulus statement will override the corresponding values set globally in the General Data Category of input.

Mandatory entries:

Optional entries:

DELH= Size of segmentation to be used in pipe/tube/annulus. This value overrides values set as default on the SEGMENT statement. However, the default does not override values that are computed under the AUTO or FAST options.

SEGM=. Number of segments to be used in the current pipe/tube/annulus. This value overrides defaults set on the SEGMENT statement. However, this value does not override segment sizes that are computed under the AUTO or FAST options.

LENGTH()= Distance from the top of the first annulus in the link to the bottom of the annulus in long length units.For an inclined well, the length will be greater than the depth.

NAME= Identifies the annulus. Used for cross-referencing. Up to four alphanumeric characters.

IDANNULUS()= Inside diameter of annulus in short length units.

ODTUBING()= Outside diameter of the tubing inside the casing which forms the annulus in short length units.

DEPTH()= Vertical depth from the well head to the bottom of the casing in long length units. Must be positive. If omitted, a vertical annulus is assumed (depth = length).





TUBING

Define the tubing in a well. Any value defined on a Tubing statement will override the corresponding values set globally in the General Data Category of input.

Mandatory entries:

Optional entries:

ROUGHNESS()=0.0018 Annulus inside roughness in short length (special) units (see Table 4-4). Use the qualifier REL to denote roughness as a fraction of the annulus inside diameter.

ISOTHERMAL or NONISOTHERMAL

Use ISOTHERMAL to suppress heat balance calculations.Use NONISOTHERMAL to override an ISOTHERMAL entry on the CALCULATION statement in the General Data Category of input and thus reinstate heat balance calculations.

FLOWEFF=100 Flow efficiency as a percentage. This parameter may be used in a rating exercise to adjust flowrates to meet a measured pressure drop. The use of FLOWEFF is recommended only when other parameters, such as pressure drop method, roughness, heat transfer coefficient values, etc., have been varied in order to match field data.

HWCOEF()=150 Hazen-Williams coefficient, for use with the Hazen-Williams pressure drop method for single-phase liquids.

U()=1.0 Overall heat transfer coefficient from inside an annulus to the surroundings.


DELH = Size of segmentation to be used in pipe/tube or annulus. This value overrides values set as default on the SEGMENT statement. However, the default does not override values that are computed under the AUTO or FAST options.

SEGM= Number of segments to be used in the current pipe/tube/annulus. This value overrides defaults set on the SEGMENT statement. However, this value does not override segment sizes that are computed under the AUTO or FAST options.

LENGTH()= Distance from the top of the first annulus in the link to the bottom of the tubing in long length units. For an inclined well, the length will be greater than the depth.

NAME= Identifies the tubing. Used for cross-referencing. Up to four alphanumeric characters.

ID()= or NOMD=

Inside diameter of tubing in short length units. Nominal diameter of tubing (in inches only).

SCHEDULE=TB01 Tubing schedule.

Note: If a nominal diameter is not available for a user-defined schedule in the selected table, then PIPEPHASE will generate an error message. If the schedule is not defined, then the default schedule TB01 is used. If a match cannot be found, PIPEPHASE will produce an error message.


STRUCTURE Data Category of Input > TUBING …

Entries for detailed heat transfer in wells:

These entries describe the casings between the outside of the tubing and the inside of the hole and the annular spaces between tubing and inner casing, between the casings and between outer casing and hole. You are allowed up to four casings. The number of spaces must be one more than the number of casings.

DEPTH()= Vertical depth from the well head to the bottom of the tubing in long length units. Must be positive. If omitted, a vertical tubing is assumed (depth = length).



ROUGHNESS()=0.0018 Tubing inside roughness in short length (special) units (see Table 4-4). Use the qualifier REL to denote roughness as a fraction of the tubing inside diameter.

ISOTHERMAL orNONISOTHERMAL

Use ISOTHERMAL to suppress heat balance calculations. Use NONISOTHERMAL to override an ISOTHERMAL entry on the CALCULATION statement in the General Data Category of input and thus reinstate heat balance calculations.

FLOWEFF=100 Flow efficiency as a percentage. This parameter may be used in a rating exercise to adjust flowrates to meet a measured pressure drop. The use of FLOWEFF is recommended only when other parameters, such as pressure drop method, roughness, heat transfer coefficient values, etc., have been varied in order to match field data.

HWCOEF()=150 Hazen-Williams coefficient, for use with the Hazen-Williams pressure drop method for single-phase liquids.

U()=1.0 Overall heat transfer coefficient from inside a tubing to the surroundings.


ODTUBING()= Outside diameter of the tubing in short length units.

IDCASING()= Mandatory entry. Inside diameter(s) of the casing(s) in short length units. Up to four entries, working outward, separated by commas.

ODCASING()= Mandatory entry. Outside diameter(s) of the casing(s) in short length units. Up to four entries, working outward, separated by commas.

HOLEID()= Mandatory entry. Diameter of the hole in short length units.

CONCASING()=25 Thermal conductivity of the tubing and casings. Up to five entries, working outward, separated by commas. The first entry is for the tubing.



EMIS()=0.95 Emissivity of the inner surfaces of casings and the hole. Up to five entries, working outward, separated by commas. Where the space is not filled with a gas, just enter a comma without a value.

EMOS()=0.95 Emissivity of the outer surfaces of the tubing and casings. Up to five entries, working outward, separated by commas. Where the space is not filled with a gas, just enter a comma without a value.

MEDIUM= Mandatory entry. Type of medium filling each space. Up to five entries, working outward, separated by commas. Media are identified by code number:

1 = gas with natural convection 2 = gas with forced convection 3 = liquid with free convection 4 = liquid with forced convection 5 = solid

CPANNULUS() =0.25 (for gas) or 0.46 (for liquid)

Specific heat of the annular medium. Up to five entries, working outward, separated by commas. Not required for a solid medium. Where the medium is solid, just enter a comma without a value.

CONANNULUS() =0.01875 (for gas) or 0.12083 (for liquid)

Thermal conductivity of the annular medium. Up to five entries, working outward, separated by commas. A value is required for a solid medium.

BETANNULUS()=0.00141 Coefficient of thermal expansion of a gas with natural convection. Only applies when MEDIUM=1 for the corresponding annular space. Up to five entries, working outward, separated by commas. Where the space is not filled with a gas with natural convection, just enter a comma without a value.

VISANNULUS() =0.0223 (for gas) or 0.22 (for liquid)

Viscosity of a gas or liquid annular medium. Up to five entries, working outward, separated by commas. Where the space is not filled with a gas or liquid, just enter a comma without a value.

VELANNULUS()= Velocity is required for a forced convection gas or liquid annular medium. Up to five entries, working outward, separated by commas. Where the space is not filled with a forced convection gas or liquid, just enter a comma without a value.

DENANNULUS() =0.0559 lb/ft3 (for gas) or 62.4 lb/ft3 (for liquid)

Density of a gas or liquid annular medium in lb/ft3 or kg/m3. Up to five entries, working outward, separated by commas. Where the space is not filled with a gas or liquid, just enter a comma without a value. Gravity units, namely SPGR and API units, are not allowed.

DIFFEARTH=0.96 Diffusivity of the earth.

CONEARTH()= Optional entry. Thermal conductivity of the earth.

TIME= Mandatory entry. Equivalent production or injection time since the last time the temperature gradient in the well was the geothermal gradient. Units must be days.

DELH = Size of segmentation to be used in pipe/tube or annulus. This value overrides values set as default on the SEGMENT statement. However, the default does not override values that are computed under the AUTO or FAST options.

SEGM= Number of segments to be used in the current pipe/tube/annulus. This value overrides defaults set on the SEGMENT statement. However, this value does not override segment sizes that are computed under the AUTO or FAST options.


STRUCTURE Data Category of Input > Dual Completions …

Dual Completions

Dual completion strings, when modeled as separate production strings (links), do not account for the heat transfer between the strings. If detailed heat transfer interactions between the strings need to be calculated, the configuration of the dual completion must be defined.

The calculation must be Network and the fluid must be Blackoil, steam or compositional. Only concentric dual completions may be modeled if the fluid is compositional. Dual completion strings are indicated by the keyword DUAL in the LINK statement.

Concentric Dual Completions

This well is modeled with two links. The first link contains the inner production or injection string which is specified on a TUBING statement. The second link models the outer string as an ANNULUS. The geometry of the annular space is defined by IDCAS and ODCAS.

To model an insulated tubing or casing, specify a solid medium for the annular space.

All the detailed heat transfer data are entered on the TUBING statement, including the thermal properties of the fluid in the ANNULUS. The ANNULUS statement does not change for detailed heat transfer calculations.

Separate TUBING statements are required whenever the tubing or heat transfer parameters change. A separate ANNULUS statement must be supplied to correspond to each length of tubing down to the first completion. Below this point, the annulus does not function as a flow device and there is no ANNULUS statement for it. It is simply a casing on the TUBING statement.

Example: LINK NAME=L1, FROM=S1, TO=SNK1, DUAL=L2 $ Surface to the bottom of the water filled space TUBING ID=2.992, ODTUBING=3.5, IDCASING=5.5,8.54, & ODCASING=5.52,9.62, HOLEID=12, CONCASING=29,29,29, & EMIS=0.9,0.9,0.9, EMOS=0.9,0.9,0.9, MEDIUM=2,3,5, & BETAN=1.39E-3,1.39E-6,0, DENAN(LBFT3)=0.055,63,0, & CONAN=1,2.9,0.5, VISAN=0.5,1,0, CPAN= 1,1,0, & VELAN=5,0,0, CONEARTH=1.0, DIFFUSIVITY=0.96, TIME=21, LENGTH=500 $ Bottom of water filled space to first completion TUBING ID=2.992, ODTUBING=3.5, IDCASING=5.5, ODCASING=5.52,& HOLEID=8, CONCASING=29,29, EMIS=0.9,0.9, EMOS=0.9,0.9,& MEDIUM=2,5, BETAN=1.39E-6,0, DENAN(LBFT3)=0.055,0, &



CONAN=1,0.5, VISAN=0.5,0, CPAN= 1,0, VELAN=5,0,& CONEARTH=1.0, DIFFUSIVITY=0.96, TIME=21, LENGTH=1000$ First completion down to the second completion TUBING ID=2.992, ODTUBING=3.5, IDCASING=5.5, ODCASING=5.52,& HOLEID=8, CONCASING=29,29, EMIS=0.9,0.9, EMOS=0.9,0.9,& MEDIUM=1,5, BETAN=1.39E-6,0, DENAN(LBFT3)=0.63,0, & CONAN=0.0188,0.5, VISAN=0.033,0, CPAN= 1,0, VELAN=5,0,& CONEARTH=1.0, DIFFUSIVITY=0.96, TIME=21, LENGTH=1500$ LINK NAME=L2, FROM=S2, TO=SNK2, DUAL=L1 ANNULUS IDAN=5.5, ODTUB=3.5, LENGTH=500 ANNULUS IDAN=5.5, ODTUB=3.5, LENGTH=1000

Parallel Dual Completions

Each production or injection strings is modeled as TUBING in a separate link. The casings around the strings are defined by the IDCAS and ODCAS keywords on the TUBING statements.

For insulated tubing, specify a solid medium for the annular space such that the insulation around each tubing is held in place by a metal sheet which is modeled as a casing. This casing, and the first casing which surrounds both strings, must be defined on each TUBING statement. Data for the other casings which surround both strings are entered for one of the links only - the longer link in the example below. Whenever a change in data requires a new TUBING statement in one link, there must also be a new TUBING statement in the other link down to the first completion. A separate TUBING statement is then required in the longer link for the remainder of the string.

Example:LINK NAME=L1, FROM=S1, TO=SNK1, DUAL=L2 $ Longer string

TUBING ID=2.441, ODTUBING=2.875 IDCASING=4.35,9.85,12.615, & ODCASING=4.875,10.75,13.375, HOLEID=17.5, & CONCASING=29,29,29,29, EMIS=0.9,0.9,0.9,0.9, & EMOS=0.9,0.9,0.9,0.9,MEDIUM=5,1,3,5, & BETAN=0,1.39E-3,1.39E-6,0, DENAN(LBFT3)=0,0.055,63,0, & CONAN=0.04,0.0188,1,0.5, VISAN=0,0.023,1,0, & CPAN= 0,0.25,1,0, VELAN=0,0,0,0, CONEARTH=1.0, & DIFFUSIVITY=0.96, TIME=21, LENGTH=500 TUBING ID=2.441, & ODTUBING=2.875, IDCASING=9.85, ODCASING=10.75, & HOLEID=12.5, CONCASING=29,29, EMIS=0.9,0.9, & EMOS=0.9,0.9,MEDIUM=1,5, BETAN=1.39E-3,0, & DENAN(LBFT3)=0.055,0, CONAN=0.0188,0.5, VISAN=0.023,0, & CPAN= 0.25,0, VELAN=0,0, CONEARTH=1.0, DIFFUSIVITY=0.96, & TIME=21, LENGTH=1000 TUBING ID=2.441, ODTUBING=2.875, & IDCASING=9.85, ODCASING=10.75, HOLEID=12.5, & CONCASING=29,29, EMIS=0.9,0.9, EMOS=0.9,0.9,MEDIUM=1,5, & BETAN=1.39E-3,0, DENAN(LBFT3)=0.055,0, CONAN=0.0188,0.5, &


STRUCTURE Data Category of Input > Parallel Dual Completions …

VISAN=0.023,0, CPAN= 0.25,0, VELAN=0,0, CONEARTH=1.0, & DIFFUSIVITY=0.96, TIME=21, LENGTH=1500$ LINK NAME=L2, FROM=S2, TO=SNK2, DUAL=L1 $ Shorter string TUBING ID=1.995, ODTUBING=2.35, IDCASING=2.875,9.85, & ODCASING=4.35,10.75, HOLEID=17.5, CONCASING=29,29,29, & EMIS=0.9,0.9,0.9, EMOS=0.9,0.9,0.9,MEDIUM=5,1,5, & BETAN=0,1.39E-3,0, DENAN(LBFT3)=0,0.055,0, & CONAN=0.04,0.0188,0.5, VISAN=0,0.023,0, CPAN= 0,0.25,0, & VELAN=0,0,0, CONEARTH=1.0, DIFFUSIVITY=0.96, TIME=21, & LENGTH=500 TUBING ID=1.995, ODTUBING=2.35, IDCASING=9.85, & ODCASING=10.75, HOLEID=12.5, CONCASING=29,29, EMIS=0.9,0.9, & EMOS=0.9,0.9,MEDIUM=1,5, BETAN=1.39E-3,0, & DENAN(LBFT3)=0.055,0, CONAN=0.0188,0.5, VISAN=0.023,0, & CPAN= 0.25,0, VELAN=0,0, CONEARTH=1.0, DIFFUSIVITY=0.96, & TIME=21, LENGTH=1000



Equipment Devices (have no length)

COMPLETION

Describes a bottomhole completion, the interface between the reservoir and a well. An IPR device should be used in addition to the completion device to account for the pressure drop from the reservoir to the near wellbore.There are two types of completion: gravel-packed; and open-perforated. The entries on this statement depend on the type of completion.

Mandatory entries for both types of completion:

Optional entries for both types of completion:

Mandatory entries for gravel-packed completion:

Optional entries for gravel-packed completion:

Mandatory entries for open-perforated completion:

JONES or MCLEOD Use one of these to indicate whether the completion is to use the Jones model for gravel-packed completions or the McLeod open-perforated completion model.

LENGTH()= Total length of the perforated interval in long length units.

PERFD()= Diameter of the perforation in short length units.

SHOTS()= Perforation shot density measured as total number of perforations per unit completion length.

NAME= Up to four alphanumeric characters.

TUNNEL()= Tunnel length that is filled with gravel through which linear flow occurs in short length units.

PERM()= 45 Permeability of the gravel.

PENETRATION()= Distance from the end of the perforation to the borehole radius in short length units.

PERM()= Crushed zone permeability. An additional qualifier must be used to indicate whether the value is for CRUSHED zone or RESERVOIR. If a reservoir value is supplied, the crushed value is calculated depending on whether the perforating conditions are declared to be overbalanced or underbalanced (see OVER and UNDER, below): Overbalanced conditions:

Crushed permeability = 0.1 * reservoir permeability Underbalanced conditions:

Crushed permeability = 0.4 * reservoir permeability No declared conditions:

Crushed permeability = reservoir permeability


STRUCTURE Data Category of Input > COMPRESSOR …

Optional entries for open-perforated completion:

Example: COMPLETION JONES, TUNNEL=1.55, PERFD=0.39, SHOTS=4, LENGTH=10COMP NAME=COMP, MCLEOD, PERM(RESE,MD)=0.65, PENE=3,&PERFD=0.39, SHOTS=8, LENGTH=30, UNDERBALANCED

COMPRESSOR

Describes a single or multi-stage compressor. This unit cannot be used for steam systems.

Mandatory entries:

Optional entries:

OVER or UNDER Use this keyword to indicate that the perforating conditions are overbalanced or underbalanced.

THICKNESS()= 0.5 Thickness of the crushed zone immediately around the perforation in short length units.

POWER()= orPRES()= orCURVE()=

One of power, outlet pressure or a compressor curve must be specified. Optionally, use the MAX qualifier to specify a maximum power or pressure. If power is specified, you may specify a maximum pressure. If you specify outlet pressure or a compressor curve, you may supply a maximum power.

or

CRVn()= and RPMC=andRPM= orPOWER= orPRES=

If a curve is entered (up to 25 entries) for a multistage compressor, all stages use the same curve. For CURVE, you can use two qualifiers to specify units of measurement for actual flowrate (gas volume basis only) and/or long length. Format of data is:CURVE=rate,head,efficiency/rate,head,efficiency/...

For multispeed curves, CRVn, RPMC, and one of RPM, PRESSURE, or POWER are mandatory. One curve must be entered for each RPMC value specified. Up to five RPMC values may be entered in ascending or descending order:RPMC=rpm1,rpm2,rpm3,rpm4,rpm5

Up to 25 data sets may be entered per curve:CRVn=rate1,head1,efficiency1/.../rate25,head25, efficiency25


STAGES=1 Number of stages.

Efficiency=100 Percentage adiabatic efficiency of the compressor. Not used if a CURVE is defined.

RPM(MAX)= For multispeed compressors, the maximum speed in RPM.

PRES(MAX)= For multispeed compressors, the maximum pressure.

POWER(MAX)= For multispeed compressors, the maximum power.



Example:COMP POWER(MAX)=55, CURVE=200,20,85/400,40,76COMPRESS NAME=CMP2, POWER(HP)=250, PRES(MAX,PSIG)=1050, &EFFICIENCY=85

Example: Multispeed compressor with data provided for three RPM curves.COMP NAME = CMP1, PRES(MAX)=300, &CRV1=200,20,100/300,40,98/ &CRV2=400,50,100/500,60,98/ &CRV3=600,70,100/700,80,98, &RPMC=1000,2000,3000

MCOMPRESS

Describes a single or multi-stage, multi-train compressor station. It can model the effect of intercoolers and scrubbers. This unit cannot be used for steam systems. You may specify the performance of a multistage compressor in one of the following ways:

• Total power: use the POWER keyword.

• Discharge pressure: use the PDISCHARGE keyword.

• Performance curve(s): use the CURVE keyword.

• Suction pressure: use the PIN keyword.

If you specify the suction (inlet) pressure, a special subnetworking algorithm is invoked. Note that this is true only for PBAL networks. The subnetworking algorithm then sizes the compressor power requirements.

Mandatory entries:

Note: For multispeed curves, if RPM, or PRES, or POWER is specified, you can supply maximum values for values not specified. For example, if you specify the RPM, then you can supply values of PRES(MAX) or POWER(MAX), but not RPM(MAX).

POWER()= Total power available to the multi-stage compressor. If you are using PDISCHARGE or CURVE to specify the performance of the compressor, you may use the MAX qualifier to specify a maximum power.

or

PDISCHARGE()= Discharge pressure. If you are using POWER or CURVE to specify the performance of the compressor, you may supply an estimated outlet pressure using the ESTI qualifier. Alternatively you may use the WARN qualifier and PIPEPHASE will issue a warning if the discharge pressure rises above the value you supply.

or


STRUCTURE Data Category of Input > MCOMPRESS …

Optional entries:

CURVE()= Performance curve(s) of flowrate, head and % efficiency for each stage. Each stage may have a separate curve. Each stage curve may have up to ten data points. If you input only one stage curve, each stage will use it. You can select standard or actual conditions as the basis for the gas flow rate measurement (standard is the default, but actual is recommended). You can use two qualifiers to specify units of measurement for actual gas volume flowrate and/or long length. Format of data is:CURVE=stage, rate, head, efficiency/stage, rate, head, efficiency/...

or

PIN()= Suction pressure. Invokes a special subnet working algorithm. If PIN is specified POWER, PDIS or CURVE must not be specified.


TRAINS=1 Number of identical compressor trains operating in parallel.

STAGES=1 Number of stages per train to a maximum of five.

EQUALPR or INTP()=

Use one of these entries to define the interstage compressor pressures. Use EQUALPR to specify that the pressure ratios across all stages are to be equal. Use INTP to set the individual interstage pressures, in ascending order, separated by commas. None of the efficiency keywords may be used with CURVE.

ADEFF= 100 Adiabatic efficiency of each stage, in ascending order, separated by commas. This keyword may not be used with CURVE.

POLY and PEFF= 100 and PEXP=

Use these keywords to specify that compression calculations are carried out using polytropic equations and to override the default data for polytropic efficiency and polytropic exponent. If you do not enter POLY, adiabatic compression equations will be used.

Use PEFF to enter the Polytropic efficiency of each stage, in ascending order, separated by commas.

Use PEXP to enter the Polytropic exponent of each stage, in ascending order, separated by commas. If you do not enter PEXP, PIPEPHASE calculates it.

INTQ() = or INTT() =

Interstage cooler duties or interstage temperatures. Up to five values, in ascending order, separated by commas.The last value refers to the duty or exit temperature of the cooler located after the last stage.

INTDP() = Pressure losses associated with interstage piping and cooler. Up to five values, in ascending order, separated by commas. The last value refers to the pressure losses associated with the piping and cooler located after the last stage.

PERCENT() = Volume percent of scrubber fluids to be reinjected downstream of the compressor station. The value is used for all scrubbers in the compressor. Use a qualifier to denote the phase to be reinjected. COND refers to the condensate phase; WATER to the free water phase. Use two entries to specify COND and WATER separately or use LIQ to refer to the combination of condensate and water.



Example:MCOMPRESS NAME=CMP1, STAGES=3, INTT(F)=120,120, TWARN(F)=250,& PDIS(PSIG,WARN)=3000, POLY, PERCENT=(COND)=100,& CURVE = 1, 50, 3000, 72/ 1, 100, 2550, 74 /& 1, 200, 2100, 75/ 1, 400, 1650, 76, ACTUALMCOMPRESS NAME=CMP2, STAGES=5, PDIS(PSIG)=1200, & INTT(F)= 100,100,100,100,100, EQUALPR,& ADEF = 80,81,80,80,82, POWER(WARN,HP)=1500MCOMPRESS NAME=CMP3, STAGES=2, POWER(HP)=800,& NOKCONV, ADEFF=79,79, INTP(PSIG)=350

COOLER

Simulates the removal of heat from a fluid. Not available with steam systems.Mandatory entries:

Optional entries:

Example:COOLER NAME=C1, TOUT=120, DP=2, DUTY(MAX)=5E3

In this example, cooler C1 has 5000 duty units available to reduce the feed stream temperature to 120F. Less duty may be used, but not more.

DPDT

Describes a general equipment item to model any device that changes the pressure and/or temperature of a fluid stream.

NOKCONV Use this keyword to suppress repeated calculations of gas specific heat ratio during convergence of the compressor. Instead, PIPEPHASE will use the inlet value throughout the compressor.

TDIS() = Warning temperature. If the calculated exit temperature exceeds this value a warning will be printed.

PRSTAGE() = Warning pressure ratio. If any calculated stage pressure ratio exceeds this value a warning will be printed.

STANDARD or ACTUAL

Compressor data are specified at standard or actual conditions. The default is to enter the data based on standard conditions.

TOUT()= or DUTY()=

Use one of these entries to define the operation of the cooler. If both are used in order to bound the outlet conditions, you must apply either the MIN qualifier to TOUT or the MAX qualifier to DUTY.


DP()=0.0 Pressure drop across the cooler.

COEFFICIENT=1.0, andEXP=1.0

Alternative method of expressing pressure drop as a function of flowrate through the cooler, in the form:

P = COEFFICIENT * RATEEXP

where the rate is always expressed in lb/sec and DP is in units of PSI. Therefore the COEFFICIENT entry has dimensions:

P / RATEEXP


STRUCTURE Data Category of Input > EXPANDER …

Mandatory entries:

Optional entries:

Example: DPDT NAME=E3, CURVE=1.5E6,7,35/0.5E6,15,40

EXPANDER

This statement is currently available only for steam systems and models the work generated due to expansion of steam from a high pressure to a lower pressure.

CURVE()= Up to 25 entries. Describes the relationship between the fluid flowrate and the pressure and temperature differences across the device. A positive difference indicates a rise in pressure or temperature across the device. The format of the data is: CURVE()= rate, dp, dt / ....

CRVn() specifies a curve in the multi-curve DPDT data. The 'n' refers to the curve number and must be a intger between 1 and 5. Example: crv1=q1,dp1,dt1/q2,dp2,dt2/…..up to 25 points. The units for rate, dp and dt can be specified locally. (GUI does not allow local units specification). This keyword not allowed to be used with the (previously existing) CURVE keyword which is allowed only for a single curve..

PINC() Inlet pressure curve parameter. The number of values must match exactly as the number of curves specified. (GUI does not allow local units specification). Maximum 5 values:eg. PINC = 100,200,300,400,500

or

POUTC() Outlet pressure curve parameter. The number of values must match exactly as the number of curves specified. (GUI does not allow local units specification).Maximum 5 valueseg. POUTC=500,600,700,800

Qualifiers may be used to specify units of measurement for flowrate, pressure and temperature. The units for flowrate allowed depend on the fluid: Fluid Type Rate Basis Non-compositional gas Std.Gas volume units Non-compositional liquid Std. Liq. volume unitsSteam Weight unitsCompositional fluid Weight unitsBlackoil Std. Liq. volume units Gas condensate Std. Gas volume units


WELL Use this keyword to indicate that the device is in a well.



Mandatory entries:

Optional entries:

Example: EXPANDER NAME=EXP1, DP(BAR)=4,EFFIC=87

GLVALVE

Describes a Gaslift Valve as part of a well LINK. Used with blackoil fluids only. The properties of the lift gas must be described in the PVT Data Section.

Mandatory entries:

Optional entries:

Example: GLVALVE NAME=GLV1, RATE(CFM)=1.5, DISSOLVE=35

HEATER

Simulates the addition of heat to a fluid. Not available with steam systems.Mandatory entries:

Optional entries:

POWER()= or Required amount of power to be produced.

DP()= or Required pressure drop.

PRATIO= or Required pressure ratio of absolute outlet pressure to absolute inlet pressure.

PRES()= Desired outlet pressure. This entry should be used for spur links only (see Flowrate Estimation in Links, p. 6-76). The qualifier MIN may be used to set the minimum outlet pressure.


EFFICIENCY=100 Adiabatic efficiency (in percent).

WTOLERANCE=0.001 Relative tolerance used to converge the power calculations.

TEST()= Estimate of the expander outlet temperature. Used to assist convergence.

RATE()= Lift gas rate in standard gas volume units.


DISSOLVE=100 Volume percentage of soluble lift gas that dissolves in the oil.

TOUT()= or DUTY()=

Use one of these entries to define the operation of the heater. If you use both, you must apply the MAX qualifier to one of the entries.


DP()=0.0 Pressure drop across the heater.


STRUCTURE Data Category of Input > INJECTION …

Example:HEATER DUTY=5E3, TOUT(MAX)=212

In the example above, the heater has a duty of 5000 units available to it, but the maximum outlet temperature is set at 212oF. Therefore, if 212oF is reached using fewer than 5000 duty units, then the heater duty will be set at the calculated value.

INJECTION

Describes a device for introducing an injection stream from a SEPARATOR to a point downstream. Used with blackoil, gas condensate or compositional fluids.

Mandatory entries:

Optional entries:

Example:INJECT FROM=V101, GAS

Note: If the user does not specify either the pressure or temperature for the injected stream, the value from the separator will be used in the energy balance. If the injection pressure differs from the pressure where the fluid is injected, the required pressure difference will be calculated.

COEFFICIENT=1.0, andEXP=1.0

Alternative method of expressing pressure drop as afunction of flowrate through the heater, in the form:

P = COEFFICIENT * RATEEXP

where the rate is always expressed in lb/sec and DP is in units of PSI. Therefore the COEFFICIENT entry has dimensions:

P / RATEEXP

FROM= Identifies the SEPARATOR STREAMID from where the injected stream was produced.

GAS or COND or WATER or LIQUID

Identifies the separator effluent stream which forms the injected stream. If you want to inject several streams from separators at the same point, use multiple INJECTION devices.


PRESSURE()= andTEMPERATURE()=

Specify either both or neither. If you specify neither, the pressure of the injected stream will be assumed to be the injection point pressure and its temperature that of the separator.

WELL Use this keyword to indicate that the injection device is in a well.



IPR

The Inflow Performance Relationship device models the relationship between flowrate and reservoir pressure draw-down or pressure drop at the sand face in a well. Several IPR models are supplied. Alternatively, user-defined IPR models may be linked to PIPEPHASE and data for them entered through the IPR device.

The IPR device is also used to enter reservoir decline data which is required for time-stepping.

The IPR device can also be used to shut-down sources depending upon wheter a maximum water cut or gas oil ratio has been exceeded in any given source.

This device also allows tabular data to be entered for interpolation or regression onto one of the PIPEPHASE models and/or for use in a time-stepping run.

Units of measurement are those chosen on the DIMENSIONS statement and cannot be changed for individual data items in the IPR device.

Mandatory entries:

MODEL= Enter a number to define a user-supplied IPR model to be used. The model number must be greater than 20 but less than 30.

or

TYPE= Enter the name of the IPR model to be used. The data required depends on the model selected. Refer to tables below:

Type Description Table

PI Productivity Index Table 4-34

VOGEL Vogel Table 4-35

GASF Fetkovich Gas Flow Table 4-36

LIT Laminar-Inertial-Turbulent (Jones and Blount) Table 4-37

BABUODEH The Babu-Odeh IPR model for horizontal wells Table 4-39

TABULAR Tabular Data Model Table 4-40

IVAL= Integer data identified by Labels. These data are input in the format:IVAL = label, value/label, value/ ...

Refer to tables below for labels and descriptions. Labels may be entered in full or may be truncated to four characters. Except where stated, these data are all mandatory.

RVAL= Real data identified by Labels. These data are input in the format: RVAL = label, value/label, value/ ...

Refer to the following tables for labels and descriptions. Labels may be entered in full or may be truncated to four characters. Except where stated, these data are all mandatory.

ARRAY= Array data identified by Labels. These data are input in the format: Array = label, value1, value2,.../label, value1, value2/ ...

Refer to the following tables for labels and descriptions. Labels may be entered in full or may be truncated to four characters. Except where stated, these data are all mandatory.

Data specified by the ARRAY keyword represents reservoir decline data.


STRUCTURE Data Category of Input > IPR …

Optional entries:

Example:IPR NAME=IPR1, GROUP=RES2, MODEL=2, & IVAL=FLOW,2, &RVAL=QMAX,0.5/VOGCON,0.3/VOGEXP,1.1/QCUM,6, &ARRAY=PPRES,5000,4500,4000,3500/ & AQCUM 7.5,6.4,5.3,4.2

NAME= Name of the Inflow Performance Relationship device.

GROUP= Name of the reservoir group. You must enter this if you want to interpolate the decline curves of a reservoir during time-stepping. The reservoir data you use can be entered in this IPR.

If you want to use reservoir decline data (defined by the ARRAY keyword) entered in another IPR device, enter the same reservoir GROUP name of the IPR device in which the data resides; do not enter any reservoir data in this IPR device.

Conversely, if you enter reservoir decline data in this IPR, the data can be used by another IPR device draining the same reservoir.

You may enter data for multiple reservoirs in one PIPEPHASE run.



Table 4-32: Label Requirements for All Models

Note: A request to shut wells may be made using any of the following criteria within the IPR device:1 If the local reservoir pressure falls below the abandonment pressure (ABAN)2 If the well-produced watercut exceeds the maximum watercut (FWMAX) when the blackoil or

condensate fluid models are used, or3 If the well produced GOR exceeds the maximum GOR (GORMAX).

Example:IPR NAME=IPR1, TYPE=PI, IVAL=FLOW,2/BASIS,5, RVAL=PI,0.5

IVAL Labels for All Models

BASIS Deliverability (flow rate) basis 1 = gas 2 = liquid 3 = oil 4 = water 5 = weight

Flow rate units in the IPR are fixed according to the BASIS chosen: BASIS Flow rate units 1 (gas) Gas volume units 2 (liquid) Liquid volume units 3 (oil) Liquid volume units 4 (water) Liquid volume units 5 (weight) Weight units

Babu-Odeh does not allow a Basis of 1 or 5

FLOW Traverse direction: 1 = forward(default) 2 = backward

Optional RVAL Labels for All Models

DPMAX Maximum pressure drawdown for the IPR device. This constraint will be activated if all three of the following conditions are satisfied:The IPR device is in a source link with the source pressure fixed. A regulator is placed on the surface (in the link) and the regulator pressure set to a very high value (higher than any pressure in the system, e.g., 99999.0). At least one device is placed downstream of the regulator.

FWMAX Maximum acceptable water cut for the well.

GORMAX GOR at which the well will shut down.

ABAN Reservoir abandonment pressure.

WABP Minimum bottomhole pressure.

OPEN Well status flag. 1 for open, 0 for close.

UPTIME Used with time stepping to define the fraction of the time the well will be open during the time step.



If you want PIPEPHASE to automatically create a sub-surface network with multiple sources and use a Numerical Finite Difference solution method, use NSEG to identify a multi-source well (number of production zones = number of segments). A typical application would be in very thick continuous formations and horizontal well completions.

Note: The Babu-Odeh model does not support automatically generated multi-source well completions.

Table 4-33: Label Requirements for Automatically Generated Multi-Source Well Completions

Example:IPR NAME=IPR1, TYPE=PI, IVAL=NSEG,5, & RVAL=PI,0.5/ID,5.4/LENGTH,30/ECHG,5.

Use the labels below when you have specified TYPE = PI:

Table 4-34: Label Requirements for the Productivity Index Model

Example:IPR NAME=IPR1, TYPE=PI, IVAL=FLOW,2/NSEG,5, &RVAL=PI,0.5/ID,5.4/LENGTH,30/ECHG,5.0

Use the labels below when you have specified TYPE = VOGEL:

IVAL Labels for Multi-Source Well Completions

NSEG Number of segments

RVAL Labels for Multi-Source Well Completions

ID Diameter of the tubing adjacent to the producing formation

LENGTH Length of the producing zone

ECHG Elevation change over the producing zone from the foot of the well to the dog-leg. Defaults to 0.0 (horizontal)

RVAL Labels for Productivity Index Model

PI Productivity index for the entire completion

or

SPI Productivity index per unit of length. Use only with Multi-source well completions (NSEG > 1)



Table 4-35: Label Requirements for the Vogel Model

Note: Typically, other values of VOGCON and VOGEXP are used to get a vogel IPR for horizontal wells.

Example:IPR NAME=IPR1, MODEL=2, IVAL=NSEG,1, & RVAL=QMAX,1000/VOGCON,0.3/VOGEXP,1.1

Use the labels below when you have specified TYPE = GASF:

Table 4-36: Label Requirements for the Fetkovich Gas Flow Model

Example:IPR NAME=IPR1, TYPE=GASF, IVAL=NSEG,1, & RVAL=COEF,1.4/EXP,0.2

Use the labels below when you have specified TYPE = LIT:

Table 4-37: Label Requirements for the Laminar-Inertial-Turbulent Model

Example:IPR NAME=IPR1, MODEL=4, IVAL=NSEG,5, & RVAL=CLAMINAR,0.5/CTURBULENT,0.3/ID,5.4/LENGTH,30

RVAL Labels for Vogel Model

QMAX Maximum flowrate or absolute open flow potential in units corresponding to the BASIS chosen

VOGCON Constant in the Vogel equation. Must be between 0.0 and 1.0. Default is 0.2

VOGEXP Exponent in the Vogel equation. Default is 1.0

RVAL Labels for Gas Flow Model

COEF Coefficient in the Fetkovich gas deliverability model

EXP Exponent in the Fetkovich gas deliverability model

RVAL Labels for Laminar-Inertial-Turbulent Model

CLAMINAR Laminar coefficient in the Laminar-Inertial-Turbulent model

CTURBULENT Turbulent coefficient in the Laminar-Inertial-Turbulent model



Use the labels below when you want to specify pseudo-pressure formulation for the Fetkovich Gas Flow or LIT IPR model with a gas basis.

Table 4-38: Label Requirements for Pseudo-Pressure Formulation

Example:IPR NAME=IPR1, TYPE=GASF, IVAL=BASIS,1/DRAW,2/NPSEG,3 & RVAL=COEF,0.5/EXP,0.8/PMAX,5000/PMIN,1000 IPR NAME=IPR1,& TYPE=LIT, IVAL=BASIS,1/DRAW,3 & RVAL=CLAMI,0.5/CTURB,0.3/MPCON,3.2

Pseudo-Pressure formulation IVAL Labels for Pseudo-Pressure Formulation

DRAWDOWN Select a type of formulation: 0 Pressure2 formulation (default) 1 M(p) formulation with integral constant = 2.01 2 M(p) formulation with integral constant = Tsc/(PscTres)3 User defined MPCONS

NPSEG Number of pressure segments for M(p) formulation. Not valid when DRAW = 0

RVAL Labels for Pseudo-Pressure Formulation

MPCONS Integral constant for the M(p) formulation. Valid only when DRAW = 3

PMAX Upper pressure limit for M(p) formulation. Defaults to reservoir pressure. Not valid when DRAW = 0

PMIN Lower pressure limits for M(p) formulation. Defaults to PRES(MIN) on DEFAULT statement. Not valid when DRAW = 0

1 The M(p) pressure formulation is given by the following equation:

where: c is the integral constant, z is the gas compressibility, and is the gas viscosity

M p cpz------ pd

po

p

=



Use the labels below when you have specified TYPE=BABUODEH:

Table 4-39: Label Requirements for the Babu-Odeh Model

Example: (See the following figure to clarify the input)IPR NAME=IPR1, MODEL=7, IVAL=BASIS,3, & RVAL=KX,4/KY,5/KZ,6/RESA,7/RESB,8/THICK,9/ & LENGTH,22/XCORD,34/Y1CORD,45/Y2CORD,56/ZCORD,67/ & RW,6/VISL,.7/FVF,4/SKIN,2

Figure 4-2: Babu-Odeh Model Example

Tabular IPR curves may be specified for a completion by inputting PWF versus QF (flowrate) for a range of reservoir pressures or cumulative reservoir production.

RVAL Labels for Babu-Odeh Model

KX Permeability in X direction (darcies)

KY Permeability in Y direction (darcies)

KZ Permeability in Z direction (darcies)

RESA Length of reservoir - perpendicular to well, i.e. X-direction (coarse length)

RESB Width of reservoir - parallel to well, i.e., Y-direction (coarse length)

THICKNESS Thickness of reservoir (coarse length)

LENGTH Length of horizontal well (coarse length)

XCORD X coordinate of horizontal well (coarse length)

Y1CORD Y1 coordinate of horizontal well (coarse length)

Y2CORD Y2 coordinate of horizontal well (coarse length)

ZCORD Z coordinate of horizontal well (coarse length)

RW Well bore radius (fine length)

VISL Fluid viscosity

FVF Formation volume factor

SKIN Reservoir infinitesimal skin



The descriptions below use the generic form of Label; e.g., PRESn. Up to five IPR curves may be entered; i.e., n may be between 1 and 5. Up to six points may be entered on each IPR curve; i.e., m may be between 1 and 6.

Table 4-40: Label Requirements for the Tabular IPR Model

Example:IPR NAME=IPR1,TYPE=TABU,IVAL=BASIS,5, & RVAL = PRES1,2500 / & PWF11,1500 / PWF12,1250 / PWF13,1000 / & QF11,25000 / QF12,30000 / QF13,35000

The following schematic illustrates tabular IPR curves:

IVAL Labels for Tabular Data

IMODEL Enter a number to define the IPR model on which the tabular data is to be regressed: 1 Productivity Index (requires 1 point on each curve) 2 Vogel (requires 1 point on each curve) 3 Fetkovich Gas Flow (requires 2 points on each curve) 4 Laminar-Inertial-Turbulent (requires 2 points on each curve).

If you do not enter a value for IMODEL (or enter 0), interpolation will be by a sectionally-continuous straight line; there will be no curve fitting and up to six points on each IPR curve may be entered. Sufficient curve data should be supplied to cover the ranges of flow encountered during calculations.

RVAL Labels for Tabular Data

PRESn Reservoir pressure on the n-th IPR curve.

or

TQCUMn Cumulative total reservoir production on the n-th IPR curve. The units depend on the fluid type: Blackoil total oil + water in liquid volume units Condensate or gas total gas produced in gas volume unitsCompositional liquid/ steam liquid in liquid volume units

or TQOCUMn Cumulative oil production on the n-th IPR curve in liquid volume units

or TQLCUMn Cumulative oil + water production on the n-th IPR curve in liquid volume units

or TQGCUMn Cumulative gas production on the n-th IPR curve in gas volume units

or TQWCUMn Cumulative water production on the n-th IPR curve in liquid volume units

PWFnm m-th flowing bottomhole pressure on the n-th IPR curve

QFnm m-th flow rate on the n-th IPR curve. The units correspond to the BASIS chosen



Figure 4-3: Tabular IPR Curves

If cumulative production is a parameter for the tabular IPR curves the following labels may be used to interpolate the set of curves.

Table 4-41: Additional Label Requirements for the Tabular IPR Model

se the labels in the following table when you want to use the PIPEPHASE time-stepping feature.

Table 4-42: Label Requirements for Time-Stepping

RVAL Labels for Tabular Data (when Cumulative Production is the Parameter)

QCUM Cumulative total reservoir production at time=0. The default is zero. The units depend on the fluid type: Blackoil total oil + water in liquid volume units Condensate or gas total gas produced in gas volume unitsCompositional liquid in liquid volume unitsUsed only if TQCUM is specified in the reservoir declining curve.

or

QOCUM Cumulative oil produced in liquid volume units at time=0. The default is zero. Used only if TQOCUM is specified in the reservoir declining curve.

or

QLCUM Cumulative liquid (oil + water) produced in liquid volume units at time=0. Used only if TQLCUM is specified in the reservoir declining curve.

or

QGCUM Cumulative gas produced in gas volume units at time=0. The default is zero. Used only if TQGCUM is specified in the reservoir declining curve.

or

QWCUM Cumulative water produced in liquid volume units at time=0. The default is zero. Used only if TQWCUM is specified in the reservoir declining curve.

ARRAY Labels for Reservoir Data

DECLINERATE P/Z decline rate per unit of production, in pressure per gas volume units. Valid for gas flow based reservoir decline.


The curve is required if an interpolation is to be made in an IPR device or time-stepping is to be used in the run. Up to 50 points may be defined on the curve for a Blackoil or Condensate run and up to 100 points for a Liquid, Compositional or Steam run.

Alternatively, for time-stepping in Gas Reservoirs, the reservoir decline can be represented as a straight line of P/Z against cumulative production by specifying the decline rate.

Note: Any difference between a user-specified source pressure and the corresponding reservoir pressure is maintained during time-stepping. A decline in reservoir pressure (Dp) with each time-step will result in a corresponding decline in the source pressure. This feature is useful when considering the effect of well location in the reservoir.

Example:IPR NAME=IPR1, GROUP=RES2, ... & RVAL=QCUM,6/ & ARRAY=PPRES,5000,4500,4000,3500/ & AQCUM 4.2,5.3,6.4,7.5,

Well Data for Time-Stepping

For time-stepping runs, curves of reservoir pressure or cumulative production against Gas-Oil Ratio, Condensate-Gas Ratio, Water Cut and Water-Gas ratio may be entered for each completion.

PPRES Array of reservoir pressures on the reservoir declining curve.

AQCUM Array of cumulative total matter produced corresponding to the reservoir pressures array. Units correspond to the chosen fluid type for the problem.

or

AQOCUM Cumulative oil produced in units corresponding to the liquid volume units chosen. Use with QOCUM if necessary.

or

AQLCUM Cumulative liquid (oil + water) produced in units corresponding to the liquid volume units chosen. Used with QLCUM iif necessary.

or

AQGCUM Cumulative gas produced in units corresponding to the BASIS chosen. Use with QGCUM if necessary.

or

AQWCUM Cumulative water produced in units corresponding to the BASIS chosen. Use with QWCUM if necessary.

ARRAY Labels for Reservoir Data


Table 4-43: Additional Label Requirements for Time-Stepping

The following example illustrates the use of two wells utilizing a single reservoir model.

Example:IPR NAME=IPR1,TYPE=PI,RVAL=PI,50/ & PRES1,2700/ PRES2,2500/,PRES3,2300/, & GOR1, 100 / GOR2, 120 / GOR3, 150 /& WCUT1, 20 / WCUT2, 21 / WCUT3, 22 & IVAL=BASIS,2, & ARRAY= AQCUM, 10000.0, 30000, 60000, 100000/ & PPRES, 2700, 2500, 2300, 2300, &GROUP=AAAA IPR NAME=IPR2,TYPE=PI,RVAL=PI,60/ &IVAL=BASIS,2, &RVAL= PRES1, 2700 / PRES2, 2500 / PRES3,2300/, &GOR1, 67 / GOR2, 72 / GOR3, 81 / &WCUT1, 8.2 / WCUT2, 9.0 / WCUT3, 10.7, &GROUP=AAAA

PUMP

Describes a single or multi-stage pump.

RVAL Labels for Tabular Data Used with Time-Stepping

PRESn Reservoir pressure on the n-th IPR curve

or

TQCUMn Cumulative total reservoir production on the n-th IPR curve. The units depend on the fluid type: Blackoil total oil + water in liquid volume units Condensate or gas total gas produced in gas volume unitsCompositional liquid/ steam liquid in liquid volume units

or

TQOCUMn Cumulative oil production on the n-th IPR curve in liquid volume units

or

TQLCUMn Cumulative oil + water production on the n-th IPR curve in liquid volume units

or

TQGCUMn Cumulative gas production on the n-th IPR curve in gas volume units

or

TQWCUMn Cumulative water production on the n-th IPR curve in liquid volume units

GORn Gas-Oil ratio corresponding to the n-th reservoir pressure or cumulative reservoir production. Use this label for Blackoil runs only.

or

CGRn Condensate-Gas ratio corresponding to the n-th reservoir pressure or cumulative reservoir production. Use this label for condensate runs only.

WCUTn Water Cut corresponding to the n-th reservoir pressure or cumulative reservoir production. Use this label for Blackoil runs only.

or

WGRn Water-Gas ratio corresponding to the n-th reservoir pressure or cumulative reservoir production.Use this label for condensate runs only.


Mandatory entries:

Optional entries:

POWER()= One of power, outlet pressure or a pump curve must be specified.

or PRESSURE()= or TYPE=0 and CURVE()=

There are normally two pump curves: Q (flowrate) against H (head) and Q against E (efficiency). If the pump is an electric submersible pump, you may supply a third curve of Q against P (motor power). You can supply these curves either in tabular form by using CURVE or as coefficiencts of quadratic equations by using HDCONS, EFFCONS, and PWRCONS.

or TYPE=0 and HDCONS= and EFFCONS= and PWRCONS= or CRVn()= and RPMC= and RPM= or POWER= or PRESSURE=

Use TYPE to specify the number of curves and whether the RILING correction for high viscosity fluids is to be used:

TYPE = 0 Two curves without RILING correctionTYPE = 1 Three curves without RILING correctionTYPE = 100 Two curves with RILING correctionTYPE = 101 Three curves with RILING correction

If you want to input curves as a table, use the following format: CURVE()=Q, H, EFF, P/Q, H, EFF, P/...

Each group of Q, H, EFF, and P corresponds to one point on the table. You can use qualifiers to specify units of measurement for actual flowrate (liquid volume basis only) and/or head in long length units and/or motor power. P (motor power) may not be input when TYPE=0 or 100.

If you want to input curves as equations, use the following format: HDCONS = hc1, hc2, hc3 EFFCONS = ec1, ec2, ec3 PWRCONS = pc1, pc2, pc3

where: hc1, hc2, hc3 are coefficients in the head/rate equation,ec1, ec2, ec3 are coefficients in the efficiency/rate equation and pc1, pc2, pc3 are coefficients in the power/rate equation.

The form of each equation is:

property = coefficient1 + coefficient 2*Q + coefficient3*Q2

where Q = flowrate

You may not use qualifiers to change the units of measurement. PWRCONS may not be input when TYPE = 0 or 100.

If you have specified power, you may also specify a maximum pressure using PRESSURE(MAX). If you have specified an outlet pressure or a pump curve or equation set, you may also supply a maximum power using POWER(MAX).

For multispeed curves, CRVn, RPMC, and one of RPM, PRESS, or POWER are mandatory. One curve must be entered for each RPMC value specified. Up to 5 RPMC values may be entered in ascending or descending order: RPMC=rpm1,rpm2,rpm3,rpm4,rpm5

Up to 25 data sets may be entered per curve: CRVn=rate1,head1,efficiency1/.../rate25,head25,efficiency25



Mandatory entries for a pump in a well:

Example:PUMP NAME=PMP1, POWER=100, PRESSURE(MAX)=300, EFFICIENCY=90

REGULATOR

Describes a device used to fix the pressure immediately downstream from it if the upstream pressure is greater.

Note: For source links with source pressure fixed, if the link maximum flowrate is specified on the LINK statement or the DPMAX is specified in the IPR device in the source link, you must specify a regulator at the surface with a very high set pressure. There must be at least one flow device downstream of this regulator.

Mandatory entries:

Optional entries:

Example:REGU NAME=R101, PRES(BAR)=2.435

In this example:

STAGES=1 Number of stages. If there is more than one stage and pump curves are entered, all stages use the same curves.

EFFICIENCY=100 Percentage efficiency of the pump. Not used if a CURVE is defined.

AUXILLIARY()1= Auxilliary power to be supplied to an electric submersible pump in addition to the power associated with the pump itself.

ALPHA1= and DEGRADATION

You may specify head degradation as a function of Gas Ingestion Percentage.ALPHA is an array of up to five Gas Holdup Percentages; DEGRADATION is an array of corresponding head degradation percentages. The format is: ALPHA = value1, value2, value3,... DEGR = value1, value2, value3,...

Each ALPHA value must have a corresponding DEGRADATION value.

SUBMERGENCE()1= Minimum submergence for an electric submersible pump, in coarse length units.

CHP()1=14.7 Casing head pressure for an electric submersible pump.

PGRAD1=0 Vertical pressure gradient in the casing tubing annulus due to the gas column above an electric submersible pump. Units are pressure per coarse length.

WELL Use this keyword to indicate that the pump is in a well.

LENGTH()= Distance from the well head to the inlet of the pump in long length units.

DEPTH()= Vertical depth from the well head to the inlet of the pump in long length units. Must be positive. If omitted, a vertical well is assumed (depth = length).

PRESSURE()= Set downstream pressure.



If Pinlet 2.435 bar, Poutlet = 2.435 bar

If Pinlet < 2.435 bar, Poutlet = Pinlet

SEPARATOR

Describes the equipment used to split some or all of the different phases from a multi-phase stream. Used with blackoil, gas condensate or compositional fluids.

PIPEPHASE models separators in networks for blackoil, condensate and compositional fluid models. There are no restrictions on the following types of separators:

1. Gas Separator in a blackoil network

2. Condensate (oil) separator in a gas condensate network

3. Water separators in a gas condensate network

4. Liquid separators in a gas condensate network

Certain restrictions apply for the following configurations:

1. Any phase separator in a compositional network

2. Any component separator in a compositional network

3. Water separators in a blackoil network

For the restricted configurations listed above, the following ruleson the placement of the separators in the network must be followed in order to provide correct simulation results:

1. The separator(s) may be located in ‘Source pressure specified’ source link(s).

2. The separator may be located in a ‘Sink rate specified’ sink link (spur sink link).

3. The separator is located in a spur link.

4. The separator may be anywhere in a network if there are no spur links in the net-work.

The separator in a network must not be located as described below:

1. Separators must not be located in a non-spur ‘junction to junction’ link (internal link) when the network has spur links.

2. Separator must not be located in a rate specified source link, where the network has spur links.

To enable the modeling of networks with separators, in configurations which are not supported currently, a workaround may be available. The basic idea is to re-configure the problem through the judicious choice of sub-network configurations as described below.


Separators are normally maintained at some design pressures. Downstream of the separator, in the same link, specify an MREG with PUPS value set to the separator design pressure (See manual for information on how to setup sub-networks properly). When this is an acceptable option from the modeling viewpoint, the resulting subnetwork will yield a valid ‘separator in network’ configuration.

Mandatory entries:

Table 4-44: Separator Options

Note: You can operate on more than one phase on a single statement. With the blackoil model, the separator can be used to specify either the percentage or rate separation of gas, or water through use of the qualifiers (GAS,WATER). When rates are specified you can also specify the units for the volumetric flow of gas or water.

Optional entries:

Optional entry for compositional fluids:

Optional entries for a bottomhole separator:

PERCENT()= or RATE()=

Use PERCENT to define what percentage of the required phase is to be removed in the effluent stream. Use RATE to define the flowrate of the required phase to be removed in the effluent stream. That which is not removed continues along the link. Identify the phase and the rate units by use of qualifiers, as in the table below. You may operate on more than one phase on the same statement.

Separator Effluent Phase Qualifier Rate Basis

Vapor GAS1 Gas Volume

Hydrocarbon liquid COND2 Liquid Volume

Aqueous WATER Liquid Volume

Hydrocarbon + Aqueous LIQ3 Liquid Volume* Compositional fluids and blackoil problems2 Compositional fluids and gas condensate problems 3 Compositional fluids only


WELL Use this keyword to indicate that the separator is in a well.

Component Specifies the percent of the component to be separated.

GIP = If a bottomhole separator is positioned below an electric submersible pump, you may use GIP to specify Gas Ingestion Percentage.

or

ODPUMP() = andIDCASING() =

If you want PIPEPHASE to calculate Gas Ingestion Percentage, you must supply ODPUMP, the outside diameter of the pump at the bottomhole separator, and IDCASING, the inside diameter of the casing containing the pump.


Example:SEPARATOR NAME=V2, PERCENT(COND)=100, PERCENT(WATER)=95

BEND

The BEND statement may be used to describe any type of bend, for example standard elbows, mitre bends, pipe bends and flanged or butt-welded elbows. A BEND may be standard or nonstandard.

Mandatory entries:

Table 4-45: Recommended Values of KMUL

Optional entries:

Note: If a nominal diameter is not available for a user-defined schedule in the selected table, then an error message will be generated by PIPEPHASE. If schedule is not defined, then the default schedule 40 is used. If a match cannot be found, PIPEPHASE will produce an error message.

ID()= or NOMD=

Inside diameter of the bend pipe in short length units. Nominal diameter (in inches).

K= or KMUL=

Enter one of these. K is the resistance coefficient. If you enter KMUL, PIPEPHASE calculates the resistance coefficient by multiplying the calculated friction factor by KMUL. If additional information is supplied, such as the angle, this data will be ignored. If you enter K for a nonstandard bend, you must enter the value for a 90o bend and PIPEPHASE will calculate the resistance coefficient for the whole bend. Recommended values of KMUL are given in the following table:

Bend Angle Recommended Values of KMUL

Standard elbow: 90° 30

Standard elbow: 45° 16

Mitre bend 90° 60

Mitre bend 45° 15


DESCRIPTION= Up to twenty characters of descriptive text for user information purposes only.

SCHEDULE=40 Pipe schedule. Internal built-in table of schedule data will be used unless the PIPSCHEDULE keyword is specified in the DEFAULT statement in the General Data Category of input. In the latter case, either a default or user-defined table of pipe schedule data will be used.

STANDARD orNONSTANDARD

Type of bend. Use STANDARD to specify a standard mitre bend or elbow; NONSTANDARD for any other kind of bend.

RADIUS()= Radius of curvature of the bend in short length units. This entry is mandatory for a NONSTANDARD bend and ignored for a STANDARD bend.

ANGLE()= Angle of the bend. This entry is mandatory for a NONSTANDARD bend and ignored for a STANDARD bend.


Example:BEND ID=10, KMUL=60BEND ID=10, KMUL=60, HOMOGENEOUSBEND ID=10, NONSTANDARD, ANGLE=60, RADIUS=30, KMUL=50

CHECK

Describes a device that allows flow only in the direction defined by the FROM and TO entries on the LINK statement.

Mandatory entries:

Optional entries:

Example:CHECK NAME=CHK1, ID(IN)=3.25, COEFF=0.91

CHOKE

Describes a device used to restrict fluid flow.

Note: If QMAX is specified in an internal link (flow from junction to junction or junction to sink) where the link flowrate is unknown, a Fortunati or UEDA choke or valve must be added as part of the link. PIPEPHASE will adjust the choke or valve size automatically as part of the network iterations in order to meet the flow constraint.

ROUGHNESS()=0.0018 Pipe inside roughness in short length units. Use the qualifier REL to denote roughness as a fraction of the pipe inside diameter.

CHISHOLM orHOMOGENEOUS

Invokes the Chisholm or Homogeneous two-phase flow model. Only applicable if the fluid is two-phase.

LAMBDA=1.0 The first parameter in the Chisholm equation.

C2=4.35 The second parameter in the Chisholm equation. The default is for a sharp 90° bend.

USER= Invokes a user-defined pressure drop method. A FORTRAN subroutine must be written and linked with PIPEPHASE.

NUMBER=1 If you have more than one identical bend, you may use this entry to specify how many there are in the link. Use this entry only when the properties of the fluid do not change significantly.

ID()= Check valve inside diameter in short length units.


COEFFICIENT=1.0 Check valve discharge coefficient.


Mandatory entries:

Note: The ID64 keyword will allow the user to specify the Choke diameter in terms of 64ths of an inch which is the common and typical approach in the field. This option is available for all the chokes. However for Case Study, Optimization, etc. data sections, the diameter variable must be referenced as ID. ID64 is used only for input and the variable is merged with ID for all subsequent processing.At least one pressure loss device before and after the choke must be present for the GF chokes to work properly.

Optional entries:

The following keywords are applicable for the Gilbert Family of choke models:

Table 4-46: GF Model Coefficients

ID()=or ID64

Choke inside diameter in short length units.ID is in fine length units. ID64 is in 64ths of an inch

FN or UEDA or ORIFICE or PERKINS

Calculation method. You must select ORIFICE if you have specified that the fluid is single-phase on the CALCULATION statement in the General Data Category of input. The FN (Fortunati) and PERKINS methods may only be used for multiphase fluids. UEDA may only be used for Blackoil. PERKINS is based on fundamental energy and mass balance equations and models both critical and sub-critical flow in a homogenous mixture with no mass exchange between phases.

GILBERT or ROSBAXENDELL orACHONG

Choke correlation for critical flow models


COEF=1.03 Choke discharge coefficient. Defaults to 1.03 for Fortunati, 1.0 for UEDA, 0.826 for Perkins and is calculated for ORIFICE.

CPCV=1.0 Specific heat ratio for the vapor phase. Used for UEDA and Fortunati only. Used for non-compositional fluids.

WELL Use this keyword to indicate that the choke is in a well.

A=() The value of the A coefficient. Default values are specified as shown in the table below, Table 4-46. The user can override these values

B=() The value of the B coefficient. Default values are specified as shown in the table below, Table 4-46. The user can override these values

C=() The value of the C coefficient. Default values are specified as shown in the table below, Table 4-46. The user can override these values

CPR=0.55 Critical pressure ratio at the onset of critical flow. The default value is 0.55.

GF Model A B C

Gilbert 10.0 0.546 1.89

Ros 17.4 0.500 2.00

Baxendell 9.56 0.546 1.93

Achong 3.82 0.650 1.88


Table 4-47: Choke Models and Applicable Fluid Types:

Besides the fluid type, a more general approach for choosing choke models in a network system are:

• Good quality results for critical and subcritical flow (Perkins).

• Accurate prediction of the boundary between critical and subcritical flow (Perkins, Fortunati)

• Smooth transition between the two types of flow (Perkins).

The last consideration is important in order to avoid convergence problems during calculations of the whole system.

Example:CHOKE NAME=CHOK, ID(MM)=25.4, FN, COEF=1.05

MCHOKE

This choke device allows you to specify the inlet pressure or flowrate through the choke. PIPEPHASE solves the upstream subnetwork for the specified pressure or flowrate. Then it solves the downstream sub-network for the same flowrate. Now with the known inlet and outlet pressure it sizes the choke.

Use MCHOKE to specify a flow boundary condition for the upstream network.

Mandatory entries:

Fluid Models Choke Models

Orifice Fortunati Ueda Perkins GF

Gas Y N N Y Y*

Liquid Y N N Y Y*

Condensate N Y N Y Y**

Blackoil N Y Y Y Y*

Steam N Y N Y N

Compositional N Y N Y Y**

* For Extended Models, see Equation 6-64 for the GF model choke. Use with caution.** Program calculates this value using equivalent Blackoil values of GOR and QL.

PUPS()= or Pressure at the upstream end of the choke.

QRATE()= or Flowrate through the choke.

PDOWN()= Pressure at the downstream end of the device. If you specify the downstream pressure, PIPEPHASE treats the device as a conventional device with a specified exit pressure and solves the network without use of the subnetwork algorithm.


Optional entries:

Example:MCHOK NAME=MCH1, PUPS=2300, CPCV=1.45

MREGULATOR

This device introduces a pressure discontinuity into the defined network structure. Other devices that invoke the same algorithm are MCOMPRESSOR and MCHOKE.

Use MREGULATOR to specify a flow boundary condition for the upstream network.

Mandatory entries:

Optional entries:

Example:MREG NAME=MRE1, QRAT=5600

CONTRACTION

Defines a contraction from a larger to a smaller diameter pipe.

Mandatory entries:


CPCV=1.4 COEF=1.0

Coefficient used by the Fortunati model.

FN or PERKINS or GF

Models maybe specified for MCHOKE.

PUPS()= or Pressure at the upstream end of the regulator.

QRATE()= or Flowrate through the regulator. For the blackoil model, you have the option of specifying the subnetwork regulator flowrate of either oil, gas, water or liquid with appropriate unit qualifiers. The default flow basis is oil. Thus you can specify QRATE(GAS or WATER or LIQUID or OIL, unit qualifiers) = for the requlator. For example, you can select QRATE(GAS,CFD) = 10, and PIPEPHASE will seek a solution such that 10 cfd of gas is passed through the regulator.

PDOWN()= Pressure at the downstream end of the device. If you specify the downstream pressure, PIPEPHASE treats the device as a conventional regulator with a specified exit pressure and solves the network without use of the subnetwork algorithm.


IDIN()= or NOMID=

Inside diameter of the inlet pipe in short length units. Nominal inlet pipe diameter (in inches).

IDOUT()= or NOMOD=

Inside diameter of the outlet pipe in short length units. Nominal outlet pipe diameter (in inches).


Optional entries:

Example:CONTRACT IDIN=6, IDOUT=4, ANGLE=135, HOMOGEN

ENTRANCE

Describes the entrance into a pipe from a larger volume such as a vessel.

Mandatory entries:

Optional entries:




Note: If a nominal diameter is not available for a user-defined schedule in the selected table, PIPEPHASE will generate an error message. If the schedule is not defined, the default schedule 40 is used. If a match cannot be found, PIPEPHASE will produce an error message.

ANGLE()=180 Angle of the contraction. A sudden contraction has a 180 degree angle.

K= Resistance coefficient. If you omit this entry, PIPEPHASE calculates a resistance coefficient.




C2=0.5 The second parameter in the Chisholm equation.


NUMBER=1 If you have more than one identical contraction, you may use this entry to specify how many there are in the link. Use this entry only when the properties of the fluid do not change significantly.

IDPIPE()= or NOMD=

Inside diameter of the downstream pipe in short length units. Nominal downstream pipe diameter (in inches).





Example:ENTRANCE IDPIPE=3.068, K=0.3, LAMBDA=1.2

EXIT

Describes the exit from a pipe into a larger volume such as a vessel.

Mandatory entries:

Note: If a nominal diameter is not available for a user-defined schedule in the selected table, an error message will be generated by PIPEPHASE. If schedule is not defined, the default schedule 40 is used. If a match cannot be found, PIPEPHASE will produce an error message

K=0.5 Resistance coefficient for sharp edged.




C2= The second parameter in the Chisholm equation. If you use the Chisholm model, you must supply a value for C2.


NUMBER=1 If you have more than one identical entrance, you may use this entry to specify how many there are in the link. Use this entry only when the properties of the fluid do not change significantly.

IDPIPE= or NOMD=

Inside diameter of the upstream pipe in short length units. Nominal upstream pipe diameter (in inches).


Optional entries:

Example:EXIT IDPIPE=2.15, K=0.7

EXPANSION

Defines an expansion from a smaller to a larger diameter pipe.Mandatory entries:

Optional entries:




Note: If a nominal diameter is not available for a user-defined schedule in the selected table, then an error message will be generated by PIPEPHASE. If schedule is not defined, then the default schedule 40 is used. If a match cannot be found, PIPEPHASE will produce an error message.

K=1.0 Resistance coefficient for sharp edged exit.




C2= The second parameter in the Chisholm equation. If you use the Chisholm model, you must supply a value for C2.


NUMBER=1 If you have more than one identical exit, you may use this entry to specify how many there are in the link. Use this entry only when the properties of the fluid do not change significantly.

IDIN()= or NOMID=

Inside diameter of the inlet pipe in short length units. Nominal inlet pipe diameter (in inches).

IDOUT()= or NOMOD=

Inside diameter of the outlet pipe in short length units. Nominal outlet pipe diameter (in inches).



SCHEDULE=40 Pipe schedule. Internal built-in table of schedule data will be used unless the PIPSCHEDULE keyword is specified in the DEFAULT statement in the General Data Category of input.

In the latter case, either a default or user-defined table of pipe schedule data will be used.


Example:EXPANSION IDIN=4, IDOUT=6, ANGLE=135

NOZZLE

Mandatory entries:

Optional entries:


ANGLE()=180 Angle of the expansion. A sudden expansion has a 180 degree angle.

K= Resistance coefficient. If you omit this entry, PIPEPHASE calculates a resistance coefficient.

CHISHOLM or HOMOGENEOUS



C2= The second parameter in the Chisholm equation. If this entry is omitted, PIPEPHASE calculates a value.


NUMBER=1 If you have more than one identical expansion you may use this entry to specify how many there are in the link. Use this entry only when the properties of the fluid do not change throughout the link.

COMP Invokes a compressible fluid expansion model. The model is for homogeneous flow and is suited for situations in which the incompressible models lead to large pressure rises across expansion. Only valid for compositional systems.

IDPIPE()= or NOMD

Inside diameter of the upstream pipe in short length units.

IDNOZZLE()= Inside diameter of the nozzle in short length units.



Note: If a nominal diameter is not available for a user-defined schedule in the selected table, then PIPEPHASE will generate an error message. If the schedule is not defined, then the default schedule 40 is used. If a match cannot be found, PIPEPHASE will produce an error message

COEFFICIENT= Flow coefficient. If this entry is omitted, PIPEPHASE will calculate a flow coefficient.

CPCV=1.4 Specific heat ratio for the vapor phase.CHISHOLM orHOMOGENEOUS


LAMBDA=1.0 The first parameter in the Chisholm equation.C2=0.5 The second parameter in the Chisholm equation.


Example:NOZZLE IDPIPE=4.6, IDNOZZLE=3.1

ORIFICE

Mandatory entries:

Optional entries:

Example:ORIFICE IDPIPE=10, IDORIFICE=6, THICK, CPCV=1.5

TEE

Defines a tee piece in a pipeline.


NUMBER=1 If you have more than one identical nozzle, you may use this entry to specify how many there are in the link. Use this entry only when the properties of the fluid do not change significantly.

IDPIPE()= or NOMD


IDORIFICE()= Inside diameter of the orifice in short length units.




THIN or THICK

Specifies whether a thin or thick orifice plate is used.If t > 10 mm use the THICK optionIf t 10 mm use the THIN optionwhere t is the thickness of the orifice plate

COEFFICIENT= Flow coefficient. If you omit this entry, PIPEPHASE calculates a flow coefficient.




C2=0.5 The second parameter in the Chisholm equation. The default is 0.5 for a thin orifice plate or 1.5 for a thick orifice plate.

CPCV=1.4 Specific heat ratio for vapor phase.


NUMBER=1 If you have more than one identical orifice, you may use this entry to specify how many there are in the link. Use this entry only when the properties of the fluid do not change significantly.


Mandatory entries:

Optional entries:

Example:TEE IDPIPE=12, KMUL=20, ROUGH(REL)=0.0001

VALVE

Defines any type of valve gate valve, globe valve, angle valve, lift check valve, swing check valve, stop check valve, ball valve, butterfly valve, plug valve, foot valve, etc.

Note: If QMAX is specified in an internal link (flow from junction to junction or junction to sink) where the link flowrate is unknown, a choke or valve must be added as part of the link. PIPEPHASE will adjust the choke or valve size automatically as part of the network iterations in order to meet the flow constraint.

IDPIPE()= or NOMD=

Inside diameter of the upstream pipe in short length units. Nominal upstream pipe diameter (in inches).

K= or KMUL=

Enter one of these. K is the resistance coefficient. If you enter KMUL, PIPEPHASE calculates the resistance coefficient by multiplying the friction factor by KMUL. Recommended values of KMUL are 20 (through run) and 60 (through branch).




Note: If a nominal diameter is not available for a user-defined schedule in the selected table, an error message will be generated by PIPEPHASE. If schedule is not defined, the default schedule 40 is used. If a match cannot be found, PIPEPHASE will produce an error message.

ROUGHNESS()=0.0018 Pipe inside roughness in short length units. Use the qualifier REL to denote roughness as a fraction of the pipe inside diameter.




C2=1.75 The second parameter in the Chisholm equation.

USER= Invokes a user-defined pressure drop method. A FORTRAN subroutine must be written and linked with PIPEPHASE. See User-Defined DP Correlations, p. 4-195, for further information.

NUMBER=1 If you have more than one identical tee, you may use this entry to specify how many there are in the link. Use this entry only when the properties of the fluid do not change significantly.


Mandatory entries:

Table 4-48: Recommended Values of KMUL

Optional entries:

IDIN()= or NOMID=

Inside diameter of the pipe in short length units. Nominal inlet pipe diameter (in inches).

IDOUT()= or NOMOD=

Inside diameter of the valve in short length units. Nominal outlet pipe diameter (in inches).

K= or KMUL=

Enter one of these. K is the resistance coefficient. If you enter KMUL, PIPEPHASE calculates the resistance coefficient by multiplying the friction factor by KMUL. Recommended values of KMUL are given in the following table.

Valve Type Recommended Values of KMUL

Check Valve 200-400

Butterfly Valve 25-45

Foot Valve 75-420

Ball Valve fully open 3

Globe Valve 50-350

Angle Valve 50-350

Swing Valve 50-100





ANGLE=180 Angle of the valve. This entry is used for a ball or gate valve with conical inlet and outlet.




C2=1.5 The second parameter in the Chisholm equation. The default is for a gate valve.

VELCON= Velocity constant. Use this entry to calculate the minimum velocity required to keep a velocity dependent valve open. Invokes an output warning if the fluid velocity is not sufficient.



Example:VALVE NAME=GAT1, IDIN=3.068, IDOUT=3, KMUL=60 $ GLOBE VALVE

VENTURIMETER

The Venturimeter only models the pressure loss up to the throat. If you wish to include the pressure recovery effect of the Venturimeter outlet, then an EXPANSION device should immediately follow downstream.

Mandatory entries:

Optional entries:

Example:VENTURI IDPIPE=12,IDTHROAT=9.5, CPCV=1.45

NUMBER=1 If you have more than one identical valve you may use this entry to specify how many there are in the link. Use this entry only when the properties of the fluid do not change significantly.

IDPIPE()= or NOMD=


IDTHROAT()= Inside diameter of the Venturimeter throat in short length units.




COEFFICIENT= Flow coefficient. If a value is not supplied, PIPEPHASE uses built-in correlations to calculate one.

CPCV=1.4 Specific heat ratio for the vapor phase.




C2= The second parameter in the Chisholm equation. If a value is not entered, the C-parameter in Eqn. 6-77, is set to 5.3.


NUMBER=1 If you have more than one identical Venturimeter, you may use this entry to specify how many there are in the link. Use this entry only when the properties of the fluid do not change significantly.


UNIT OPERATIONS Data Category of Input

Overview

The UNIT OPERATIONS Category of input allows unit operations to be included in a simulation. UNIT OPERATIONS differ from FITTINGS and DEVICES in that they have more than one statement. The general format is:

UnitKeyword NAME=

statementName keywords...

statementName keywords...


UNIT None p. 138

CALCULATOR Unit Operation

CALCULATOR ({UID=, NAME=]

DIMENSION C(50), P(50), V(200), R(200), IX(9) p. 139

CONSTANT i, j, value/ ... p. 139

DEFINE P(i) AS SIMU = SIMU, CCLASS=<CClass>, CNAME=<CName>,VARIABLE=”<Variable Name>”, {INDEX=<Index No>}

RESULT i, text/... p. 140

PROCEDURE None p. 141

FORTRAN Statement p. 141

{DIMENSION var(), var(),...} {INTEGER var, var,...} {REAL var, var,...} {nn var = expression} {nn GOTO mm} {nn CONTINUE} {nn IF (expression) conditional clause} {nn IF (expression) THEN} {ELSEIF (expression) THEN} {ELSE} {ENDIF} {nn DO mm IXi=i, j, k} {nn DISPLAY R(i:j), P(i:j), C(i:j), V(i:j), IX(i:j)} {nn OPEN(FILE=field, OVERWRITE or APPEND) {nn OUTPUT R(i:j), P(i:j), C(i:j), V(i:j), IX(i:j)} {nn TRACE option} {nn STOP}


UNIT

Introduces the section.

Mandatory entries: None.Optional entries: None.

CALCULATOR

Introduces the Calculator unit operation. Calculator is a versatile utility module offering much of the calculational power of FORTRAN. As a unit operation module, it may be placed anywhere in the flowsheet calculation sequence. Using a simple language based on FORTRAN 77, it computes a result or array of results for printout, for storage in a stream vector, or for use by other unit modules. Its usefulness is limited only by the imagination of the user. Typical applications include:

• Compute special stream properties for use by when optimizing the flowsheet.

• Compute process utility or operating costs for printout, convergence control or opti-mization.

• Compute equipment size and cost, based on calculated unit parameters, for printout or optimization.

The CALCULATOR has two main sections:

• Calculator Setup

and

• Calculator Procedure.

The Calculator Setup section retrieves flowsheet variables involved in the calculations, dimensions certain supplied arrays, defines invariant constants, sequences streams for DO loop processing, and assigns descriptive labels to elements of the RESULTS vector. The Calculator Procedure section contains FORTRAN-based statements which perform calculations.

Mandatory entries: None.

HYDRATES Unit Operation

HYDRATES {NAME=} p. 144

EVALUATE STREAM=, {PRES()=-13.221, MAXPRES()=5861.31 and/or POINTS=30 and/or DP()=, TESTIMATE=, ITEMP(), MAXTEMP()=, and/or POINTS=30 and/or DT()=, PTESTIMATE=, INHIBITOR(type)=}

p. 145



Optional entries:


DIMENSION

Optional statement in the Calculator Setup section of the Calculator unit. The DIMENSION statement overrides default dimensions to declare the number of elements in CALCULATOR supplied arrays C, P, V, R, and IX.


CONSTANT

Mandatory statement only if the code in the Calculator Procedure section references streams or cycles through a series of sinks, sources, or junctions using a DO loop. The CONSTANT statement allows initialization of numerical values that remain unchanged by any calculations in the procedure section. Note that integer values are converted to floating-point numbers. All these constants are stored in array “C’’. The number of elements in this array may be defined on the DIMENSION statement. Elements not defined on the CONSTANT statement have large negative values.

UID= Unit identifier of the Calculator unit operation. Up to four alphanumeric characters. Embedded blanks are not permitted

NAME=) Name of the Calculator unit operation. Up to four alphanumeric characters.


GUI Coordinates to place the icon on the PFD.The user should not change this data..

C(index) Constant values defined in the Calculator Setup section. Used only on the right hand side of assignment statements

P(index) Flowsheet parameters set by DEFINE statements. Used only on the right hand side of assignment statements.

V(index) A floating- point work array used on either the left or right hand side of assignment statements. These elements are initialized to a large negative value and are not available outside the calculator.

R(index) The array of calculator results, used on either side of assignment statements. This results vector is available to other flowsheet modules external to the CALCULATOR. These elements are initialized to a large negative value.

IX(index) An array of integer values. The form “IX(index)” is invalid on a DO statement. It may be used on either side of assignment statements.


Mandatory entries:

Note: When “j’’ is given, all elements of array “C’’ between “i’’ and “j’’ assume the specified value. If “j’’ is omitted, the single element specified by “i’’ is used. When “i’’ is missing, the next available element takes the specified value.

Example: To initialize elements 3 through 11 of array “C’’ to zero, and elements 12 through 14 to 1.0, use:

CONSTANT 3, 11, 0.0/ 12, 14, 1.0

DEFINE

Optional statement. DEFINE allows retrieval of device or source/sink/junction values from the flowsheet, and stores them as elements of the “P’’ array. Each DEFINE statement initializes a single element. The number of elements in the “P’’ array may be defined on the DIMENSION statement.

Mandatory entries: DEFINE P(i) AS SIMU=SIMU, CCLASS=<CClass>, CNAME=<CName>, VARIABLE=“<Variable Name>”, {INDEX=<Index No>}

Example:DEFINE P(1) AS SIMU=SIMU, CCLASS=SOURCE, CNAME=S001, VARIABLE="Temperature"DEFINE P(3) AS SIMU=SIMU, CCLASS=SOURCE, CNAME=S001, VARIABLE="XLFEED(M)",* INDEX=1

Note: Most CALCULATORS have as a minimum one DEFINE statement.

RESULT

Optional statement. The RESULT statement allows the user to supply descriptive labels for each CALCULATOR result.

i, j These positive integers denote the beginning and ending element index in the CONSTANT array.

value The value stored in elements “i’’ through “j’’ of array C. Integer values are stored as floating-point numbers.

CCLASS = This refers the CCLASS of the device. All the valid entries for <CClass> are listed in Table 4-55a in CASE STUDY Data Category of Input starting on p. 153.

CNAME = This refers the Name of the NODE or LINK or DEVICE or PVT.

VARIABLE = This refers the Parameter. All the valid entries for <Variable Name> are listed in Table 4-55a in CASE STUDY Data Category of Input starting on p. 153.

INDEX = This refers the Array element index for Array variables (Component Mol Fractions, DPDT Curves, etc.)


Mandatory entries:

Example:RESULT 1, RELATIVE MB

PROCEDURE

The PROCEDURE statement is required.


FORTRAN Statements

Optional statements. You may supply any number of the following FORTRAN-like statements between the required PROCEDURE and RETURN statements. Each statement contains a maximum of 80 characters. An ampersand (&) at the end of a line indicates continuation on the following line. Note that an asterisk ( * ) is not valid as a continuation marker, since it signifies multiplication.

All lines of code except the PROCEDURE statement may be preceded by a unique numeric label from 1 to 99999 (shown as “nn’’ in this manual). The dollar sign ($) causes all following data on the remainder of the line to be interpreted as a comment rather than as code.

Note: Unlike FORTRAN, a “C’’ in column one does not designate a comment statement.

Example:DIMENSION A(20,20), B(20), X(20)REAL MASSINTEGER COUNT, TAB(100)

Five real values are to be specified for the revenue (REVENU), profit (PROFIT), and loss (LOSS) arrays corresponding to the years 2006 through 2010. The integer constants 2006 and 2010 are used (separated by commas) to denote the array bounds.

Example:REAL REVENU(2006:2010), PROFIT(2006:2010), LOSS(2006:2010)

i, text/... Descriptive label for each calculator result. Labels may consist of up to 12 characters of text, but must not contain the characters = , ( ) * or &. Embedded blanks are acceptable.

Statement Description

{DIMENSION var( ), var( ), ...} The DIMENSION statement is used to define one or two-dimensional arrays. Each subscript may be an integer constant, or two integer constants separated by a colon to specify both the lower and upper array bounds.

{INTEGER var, var, ...} Defines integer variables.

{REAL var, var, ...} Defines real variables.


A variable may only appear once on these statements. The following is valid in standard FORTRAN, but not in the CALCULATOR:

Example:REAL MOLWTDIMENSION MOLWT(50)

Both standard FORTRAN and the CALCULATOR accept this equivalent form:

REAL MOLWT(50)

Expressions

Table 4-49: Mathematical Operators

The operations on a given statement are executed in the following order:

1. Expressions within parentheses ( )

2. Functions

3. Exponentiation ( ** )

4. Multiplication and division ( * ,/)

5. Addition and subtraction (+,-)

For calculations with the same precedence, expressions are evaluated from right to left for exponentials, and left to right for all others.

Note: The CALCULATOR-supplied arrays C and P may not appear on the left side of an assignment statement.

{nn var = expression} The “expression’’ is governed by standard FORTRAN conventions. The symbols for mathematical operations are given in Table 4-49 below.

Symbol Description

+ addition

- subtraction

* multiplication

/ division

** exponentiate (raise to a power)


Table 4-50a: Logical Operators in IF Statements

Table 4-50b: CALCULATOR Statements

Operator Description

.EQ. equal to

.NE. not equal to

.LT. less than

.GT. greater than

.GE. greater than or equal to

.LE. less than or equal to

.AND. both true

.OR. either true

.EQV. equivalent

.NEQV. not equivalent

.NOT. true/ false toggle


{nn GOTO mm} This is the standard FORTRAN statement that branches to label mm unconditionally. “GO TO” written as two words is also supported.

{nn CONTINUE} This statement serves as a branch destination or the end of a DO loop. It performs no calculations.

{nn IF (expression) conditional clause}

This statement allows logical branching during calculations and conforms to standard FORTRAN rules for “IF’’ statements. If the parenthetic expression is true, it executes the conditional clause, which may be any procedure section statement except RETURN, IF or DO. Table 4-50a lists logical operators allowed in the expression.

{nn IF (expression) THEN}

{ELSEIF (expression) THEN}

{ELSE}

{ENDIF} The standard FORTRAN block “IF” statements are also supported. “ELSE IF’’ and “END IF’’ written as two words are also accepted. Block “IF’’ constructs may be nested.

DO mm IXi= i, j, k} This statement defines the beginning of DO loops having a range extending through statement label mm. IXn requires integer values for the initial and final indices “i’’ and “j’’. The incremental step index “k’’ is optional and defaults to 1.

{nn DISPLAY R( i : j ), P( i : j ), C( i : j ), V( i : j ), IX( i : j )}

The DISPLAY statement prints out array values during calculations. Only CALCULATOR supplied arrays may appear in DISPLAY statements. The position of DISPLAY statements in the procedure section determines when values are printed. Entries “i’’ and “j’’ refer to the first and last elements of the array to print. If “i’’ and “j’’ are absent, the entire array is printed.


RETURN

The RETURN statement is required.


HYDRATES

Introduces the Hydrates unit operation, which predicts the pressure and temperature regime in which the fluid at a node (source, sink, or junction) is vulnerable to hydrate formation. Different ranges of temperature and pressure can be examined. Calculations assume the presence of free water for hydrates to form.

The effect of NaCl, methanol, ethylene glycol, di-ethylene glycol and tri-ethylene glycol hydrate inhibitors can also be studied.



{nn OPEN(FILE=fileid, OVERWRITE or APPEND)

The OPEN statement opens a file for CALCULATOR output. Only CALCULATOR supplied arrays may be used. For PC, VAX, and UNIX platforms, the default output name is <fileid>.CAL, where <fileid> is the current input file name. A unique filename, up to 12 characters long, may be specified, if necessary. However it will have a “.CAL’’ extension. Underscore characters are not allowed (e.g., FILE_01). Any OPEN statement automatically closes the previously opened file.

{nn OUTPUT R( i : j ), P( i : j ), C( i : j ), V( i : j ), IX( i : j )}

The OUTPUT statement performs the actual write to files. Multiple OUTPUT statements may be supplied and may appear at any time following an OPEN statement. Entries “i’’and “j’’are defined as for the DISPLAY statement. If “i’’and “j’’are absent, the entire array is printed.

{nn TRACE option} Trace statements control printing an historical trace as calculations proceed. This facilitates debugging the code in the CALCULATOR procedure. Options are:

ON Prints line number, statement number, and (action taken/ new variable value) as each statement executes.

BRANCH Prints TRACE information only for branching statements such as IF, GOTO or DO.

OFF Turns off all TRACE options.

{nn STOP} This statement stops all flowsheet calculations and proceeds directly to the output report. The solution flag for the entire flowsheet is set according to the user-defined value of ISOLVE.

NAME= Name of the Hydrates unit operation. Up to four alphanumeric characters.


GUI Coordinates to place the icon on the PFD.The user should not change this data..



EVALUATE

Mandatory statement. Define one range of conditions through which hydrate formation is to be investigated.

You may either define a range of pressures and PIPEPHASE will predict the temperature profile which defines the incipient formation of hydrates, or you may define a range of temperatures and PIPEPHASE will predict the pressure profile which defines the incipient formation of hydrates. You may optionally define an inhibitor whose effect is to be examined.

Mandatory entries:

Optional Entries for Pressure Range:

Mandatory Entries for temperature range:

Optional Entries for pressure and temperature range:

Example:UNIT OPERATIONSHYDRATES NAME=HYD1 EVALUATE STREAM=SNK3, IPRES=50, MAXPR=500, DP=10,& INHIB(EG)=12 EVALUATE STREAM=JCT1, ITEMP=200, MAXTEMP=2000, POINTS=20

STREAM= Name of the node SOURCE, SINK or JUNCTION at which the fluid is to be investigated.

IPRES()=-13.221 Specify the initial pressure at which hydrate formation is to be investigated. The default is equivalent to 0.1 ATM.

MAXPRES()= 5861.31 and/or POINTS=30 and/or DP()

Enter two out of three of: final pressure; number of points to be evaluated between the initial and final pressures (maximum is 30); pressure increment between points. The default for MAXPRES is equivalent to 400 ATM.

TESTIMATE= Estimate of incipient hydrate formation temperature at the initial pressure point.

ITEMP()= Specify the initial temperature at which hydrate formation is to be investigated.

MAXTEMP()= and/or POINTS=30 and/or DT()=

Enter two out of three of: final temperature; number of points to be evaluated between the initial and final temperatures (maximum is 30); temperature increment between points.

PESTIMATE= Estimate of incipient hydrate formation pressure at the initial temperature point.

INHIBITOR(type)= Weight percent concentration of inhibitor. If you omit this entry, noinhibitor calculations are performed. Use the qualifier to define the type of inhibitor. Allowable types are: NACL or SALT sodium chloride METH or MEOH methanol EG ethylene glycol DEG di-ethylene glycol TEG tri-ethylene glycol


EVALUATE STREAM=SRC2, INHIBITOR(NACL)=22.5

GASLIFT Category of Input

Gaslift analysis is used to investigate the effects of lift gas on well production. This feature is restricted to Blackoil wells where the oil production is upward through the well tubing and the lift gas is injected downward through the well casing.

Overview

There are four options for gaslift calculations:

1. Pressure profiles for fixed oil production rate and lift gas rate.

2. Oil production versus lift gas injection rate.

3. Location of gas injection valve to match desired tubing head (production string) pressure.

4. Location of gas injection valve to match desired casing head (injection string) pres-sure.

All gaslift options have several common factors:

• Production fluid is restricted to blackoil.

• PVT data sets must be provided for the blackoil and lift gas.

• The blackoil is described as the SOURCE fluid. Well IPR data are provided in the form of PI or Vogel coefficients. For options 1 and 2 only, well test data (on the WTEST statement) may be used to calculate the IPR.

• The SINK statement is used to provide the tubing (oil production) wellhead pres-sure.

• The production string LINK must be named “PROD”. This link may include surface and some types of equipment as well as tubing for all options except Option 4 which is restricted to tubing only.

• Applicable pressure drop methods should be selected for the oil and lift gas flow devices.

• The lift gas injection string LINK must be named “GASL”. This link must consist of only annuli, corresponding to the well casing. No other types of flow or point devices are allowed. The lift gas is always injected down the casing, enters the tub-ing at the specified valve location and then flows up the tubing with the reservoir oil and gas.

• For all options, the lift gas rates are user-specified.


In terms of problem input, all data categories are identical for the four Gaslift options except the GASLIFT Category. This category is used to select the desired Gaslift option. The following input statements are required for all Gaslift options:

Table 4-51: Gaslift Category of Input

GASLIFT

Introduces the section.


PCALC

Statement used for Gaslift Option 1 only.

Category Statement Description

GENERAL TITLE Introduces the Category

CALC Used to specify the GASLIFT calculation

PVT DATA PVT DATA Introduces the Category.

SET Used to identify the set number and to enter gravity and other data.

LIFTGAS Used to define lift gas properties.

STRUCTURE STRUCTURE Introduces the Category.

SOURCE Used to define a point where fluid enters the system

SINK Used to define a point where fluid leaves the system, including estimating or defining outlet pressure and flowrate.

LINK Used to define a series of devices (flow devices, fittings and items or process equipment).

TUBING Used to define the tubing in a well.

PIPE Used to define the pipes.

ANNULUS Used to define a well annulus

GASLIFT GASLIFT Introduces the Category.

PCALC Used to enter data for GASLIFT option 1.

CAPACITY Used to enter data for GASLIFT option 2.

LOCATION Used to enter data for GASLIFT options 3 and 4.

Statement Keywords See ...

GASLIFT None p. 147

{PCALC} PRESSURE()=, TEMPERATURE()=, RATE()=, DEPTH()=, {DISSOLVE=100}

p. 147

{CAPACITY} PRESSURE()=, TEMPERATURE()=, RATE()=, DEPTH()=, {DISSOLVE=100}

p. 148

{LOCATION} PRESSURE()=, TEMPERATURE()=, RATE()=, DEPTH()=, {DISSOLVE=100}, ID()=, IDTUBING()=, COEFFICIENT=

p. 148


Mandatory entries:

Optional entries:

Example:PCALC PRES=950, TEMP=100, DISSOLVE=0, DEPTH=5900, RATE=1.0

CAPACITY

Statement used for Gaslift Option 2 only.

Mandatory entries:

Optional entries:

Example:CAPACITY PRES=950, TEMP=100, DISS=0, DEPTH=5100, & RATE=0.001/0.2/0.4/0.6/0.8/1.0/2.0/3.0/4.0

LOCATION

Statement used for Gaslift Options 3 and 4.

Mandatory entries:

PRESSURE()= Lift gas injection pressure at casing head.

TEMPERATURE()= Lift gas injection temperature at casing head.

RATE()= Lift gas injection rate in gas volume units.

DEPTH()= Vertical depth from well head to lift gas injection valve in long length units.

DISSOLVE= 100 Percent of soluble lift gas which dissolves in the well fluid, if conditions permit.



RATE()= Up to nine lift gas injection rates in gas volume units, in ascending order, separated by commas. Zero or negative entries are not allowed.

DEPTH()= Vertical depth from well head to lift gas injection valve in long length units.




RATE()= Injection rate in gas volume units. Zero or negative entry is not allowed.

DEPTH()= Up to eight vertical depths from well head to lift gas injection valves in long length units, in ascending or descending order, separated by commas.


Optional entries:

Additional entries for Gaslift Option 4:

Example:LOCATION PRES=750, TEMP=60, DISSOLVE=100, RATE=0.185, & DEPTH=5500/5000/4500/4000/3000/2500/2000LOCATION PRES=600, TEMP=80, RATE=0.4, & DEPTH=10000/9500/9000/8500/8000/7500/7000/6500/6000, & ID=0.125/6,0.25, IDTU=2.441/6,3.548, COEF=0.9/6,0.83


ID()= Orifice inside diameters, in short length units, corresponding to the gas-lift injection valves. Format is:

ID=valve number,valve ID/valve number, valve ID/...Inside diameters of missing valves default to the previous value.

IDTUBING()= Inside diameters of tubing above Gaslift valves, in short length units, corresponding to the gas-lift injection valves. Format is:

ID=valve number,tubing ID/valve number, tubing ID/...Inside diameters of missing tubings default to the previous value.

COEFFICIENT= Orifice coefficients corresponding to the gas-lift injection valves. Format is: ID=valve number, coefficient/valve number, coeff./...

Coefficients of missing tubings default to the previous value.


SIZING DATA Category of Input

Overview

The Sizing Data Category of input sizes pipes, and tubing . This category is optional. Note that sizing is not available for depressuring only simulations as no network calculations are performed for this case.

Table 4-52: Sizing Data Category of Input

SIZING

Introduces the category. This category is used for sizing pipes and tubing.


DEVICE

Identifies which pipe and tubing devices are to be sized.

Mandatory entries:

Example:DEVICE NAME=PIP1, LIN2, PIP3

LINE

Optional statement. Defines the line sizes that are to be used by PIPEPHASE in determining a diameter which satisfies the sizing criteria. If this statement is omitted, standard API Schedule 40 inside diameters are used. These are (in inches):


SIZING None p. 150

DEVICE NAME= p. 150

{LINE} ID()= or NOMD= p. 150

{MAXV} ERVELC=, VELOCITY()=, ID()= or DENSITY()= or NOMD= p. 151

NAME=name,name,... Enter the name(s) of the device(s) that you want sized. If you want all devices to be sized, enter:

NAME=ALL

1.049 1.610 2.067 2.469 3.068 3.548 4.026 5.074 6.0657.981 10.020 11.938 13.124 15.000 16.876 18.814 22.626


Mandatory entries:

Example:LINE ID(MM)=26, 30, 35, 40

MAXV

Optional statement. Enter the maximum velocity criteria. If this statement is omitted, PIPEPHASE will use the erosional maximum velocity criteria, VEM.

Mandatory entries: (for single-link, non-flare systems only)

Example:MAXV VELOCITY=20,300,22,19,18, ID=2,5.5,10,15,25

ID()=value,value,...orNOMD=value,value...

Enter the inside diameters to be tried in short length units. Entries must be in ascending order.Enter the nominal sizes to be tried in inches. Entries must be in ascending order. Default SCHEDULE is used to get corresponding ID. If the NOMD is not in the SCHEDULE list, it is ignored.

ERVELC= or Enter the erosional velocity constant to replace 100 in the above erosional velocity equation.

VELOCITY()= Enter a set of maximum velocities corresponding to a set of inside diameters or densities.

ID()= orDENSITY()= orNOMD=

Enter a set of inside diameters or two-phase slip densities corresponding to the set of maximum velocities. Entries should be in ascending order. ID is in short length units. NOMD is in inches and the default SCHEDULE is used to get corresponding ID. If the NOMD is not in the SCHEDULE list, it is ignored.

VEM100

TwoPhaseSlip

---------------------------------------=


TIME-STEPPING Data Category of Input

The Time-Stepping Data Category of Input allows you to examine how network performance is affected as reservoir pressure declines with cumulative production and as changes are made to devices in the network.

After the initial solution of the network, you may impose changes and stipulate that those changes take place at different times. For every time entered, the network is simulated incorporating the changes you have specified up to and including that time using the condition of the reservoir (or reservoirs) at the time of the change. A full set of results is printed for every time step – this can result in significant printout.

Declining reservoir condition curves are input as tables in one or more of the IPR devices in the Structure Data Category of input.

Note: This category is also used to determine the length of time between steps. Shorter time steps are more accurate than longer time steps

Table 4-53: Time-stepping Data Category of Input

TIMESTEPPING

Introduces the category. This category is evaluate effects of changes in reservoir conditions.


CHANGE

Mandatory statement. On each CHANGE statement enter the changes to be made to one device and the times at which the changes are to be effected. More than one change statement may be used. If you do not want to change a device but simply want to examine the effect of declining reservoir conditions with an unchanging network, simply enter one CHANGE statement with a series of times.


TIMESTEPPING None p. 152

CHANGE CCLASS=<CClass>, CNAME=<CName>, {LINK=<Link Name>}, VARIABLE=<Variable Name>, {INDEX=<Index No>}, {SETCALC=}, TIME=<Time>, VALUE=<Value>

p. 152

CCLASS= This refers the CCLASS of the Device. All the valid entries for <CClass> are listed in Table 4-55a in CASE STUDY Data Category of Input starting on p. 153.


TIMESTEPPINGCHANGE CCLASS=PIPE, CNAME=PIP1, VARIABLE=PIPE ID, TIME=10, 20, 30,* VALUE=4.0, 3.5, 3.0CHANGE CCLASS=SOUR, CNAME=FEED, VARIABLE=PRESSURE, SETCALC=C1.CLC,* TIME=10,30, VALUE=0001,0001CHANGE CCLASS=PIPE, CNAME=GNETWORK, VARIABLE=PIPE ID, TIME=20, 40, VALUE=2,3CHANGE CCLASS=PIPE, CNAME=GLINK, LINK=L001, VARIABLE=PIPE LENGTH, TIME=10,30,* VALUE=10,50

Time-step changes will be taken as follows for this example:

TIME=10, 20, 30, 40 days

CASE STUDY Data Category of Input

Overview

The CASE STUDY Data Category of Input allows you to modify the base case input and re-run the simulation. This category is optional. CASE STUDY and TIME-STEPPING Data Categories of input are mutually exclusive.

Table 4-54: Case Study Category of Input.

CNAME = This refers the Name of the NODE or LINK or DEVICE or PVT. Use GNETWORK to make GLOBAL changes in the network. Use GLINK along with LINK = <Link Name> to make GLOBAL changes in a particular Link <Link Name>.

LINK = Indicates that variable changes are to be for all Devices in the link <Link Name>. This is used along CNAME = GLINK option.

VARIABLE = This refers the Parameter. All the valid entries for <Variable Name> are listed in Table 4-55a in CASE STUDY Data Category of Input starting on p. 153.

INDEX = This refer the Array Element Index for Array Variables (Component Mol Fractions, DPDT Curves, etc.)

SETCALC = Name of Calculator to retrieve data from.

TIME = The times, in days, at which the parameter(s) on this CHANGE statement are to be changed. A maximum of 20 times may be used in any one CHANGE statement. Use multiple change statements to specify more time steps.

VALUE = Enter up to 20 change values in the value of the identified variables. Should be equal to the number to Time steps entered.


CASESTUDY None p. 154

{DESCRIPTION} any text string p. 154

{RESTORE} None p. 154

{PARAMETER} CCLASS=<CClass>, CNAME=<CName>, {LINK=<Link Name>}, VARIABLE=<Variable Name>, {INDEX=<Index No>}, {SETCALC=}, VALUE=<Value>

p. 154


CASESTUDY

Introduces the category. Each new case is headed by a CASE statement and there are no limits on the number of cases which can be entered in a simulation input.


DESCRIPTION

Optional statement. Allows you to enter a description of the simulation. You are restricted to one DESCRIPTION statement per case study. The information on this statement is printed once at the start of the case study output.

Mandatory entries: NoneOptional entries: Text string of up to 60 characters.Example:DESC Change pipeline ID to 3 inches

RESTORE

By default, each new case study uses the solution from the previous case as the initial guess. Use this keyword to restore the original solution as the initial guess. Case study changes are cumulative, but the restore option will reset device and node data back to the base case values. Changes to compositions and some simulation data such as viscosity data are not included in this logic and must be restored manually.

PARAMETER

This PARAMETER statement allows changes to be made to parameters on a node and/or device. You may have as many PARAMETER statements as desired. The devices and parameters that can be changed are listed in Table 4-55a.

CCLASS= This refers the CCLASS of the device. All the valid entries for <CClass> are listed in Table 4-55a

CNAME= This refers the Name of the NODE or LINK or DEVICE or PVT.Use GFROM and GNETWORK to make GLOBAL changes in the network.Use GLINK along with LINK = <Link Name> to make GLOBAL changes in a particular Link <Link Name>.

LINK = Indicates that variable changes to be made for all devices in the link <Link Name>. This is used along CNAME = GLINK option.

VARIABLE= This refers the parameter. All the valid entries for <Variable Name> are listed in Table 4-55a.

INDEX= This refer the Array Element Index for Array variables (Component Mol Fractions, DPDT Curves, etc.)

SETCALC = Name of Calculator to retrieve data from.

VALUE= The new value to which you want the parameter changed.

The following keywords are only applicable to the optimizer.


Example: Global variable change for pipes in network to 10 inch I.DPARAMETER CCLASS=PIPE, CNAME=GNETWORK, VARIABLE= PIPE ID, VALUE=3PARAMETER CCLASS=TUBI, CNAME=GFROM, VARIABLE= PIPE ID, VALUE=2

Example: Flow code changes for tubing in network using the BBM correlation to the OLGA correlation.

PARAMETER CCLASS=TUBI, CNAME=GFROM, VARIABLE=FLOW CODE, VALUE=BBMPARAMETER CCLASS=TUBI, CNAME=GNETWORK, VARIABLE=FLOW CODE, VALUE=OLGA

Sources

Table 4-55a: SOURCE (CCLASS = SOURCE) – Case Study, Time Stepping, Optimization & Calculator Variables:

CONLOWER Absolute lower values for optimizer constraint variables are changed (Applies to valid constraint variables only.)

CONUPPER Absolute upper values for optimizer constraint variables are changed (Applies to valid constraint variables only).

Variable

Available as a

VariableDescription

Parameter Change Decision

Objective Constraint

Define

Fluid Type = CompositionalRATE(M) Molar Flow Rate X XRATE(WT) Weight Flow Rate X XRATE(LV) Standard Liquid Volume Flow Rate X XRATE(GV) Standard Gas Volume Flow Rate X XERATE(WT) Weight Flow Rate Estimate X XERATE(LV) Std Liquid Volume Flow Rate Estimate X XERATE(GV) Standard Gas Volume Flow Rate Estimate X XTEMPERATURE Temperature X XPRESSURE Pressure X XEPRESSURE Pressure Estimate X XGAS VISC Gas Viscosity XOIL VISC Oil Viscosity XWAT VISC Water Viscosity XGAS FRACTION Gas Fraction XLIQ FRACTION Liquid Fraction XGAS MW Gas Molecular Weight XOIL MW Oil Molecular Weight XWAT MW Water Molecular Weight XAVG MW Average Molecular Weight XTOTAL ENTH Total Enthalpy XGAS DENSITY Gas Density XOIL DENSITY Oil Density XWAT DENSITY Water Density XXLFEED(M) Component Mole Fractions X XXLFEED(WT) Component Weight Fractions X XWOBBE Wobbe Index XGHV Gross Heating Value XGRATE WT S Gas Weight Rate @ Std Conditions X


GL RTE GV S Gas Lift Volume Rate @ Std Conditions XGL RTE WT S Gas Lift Weight Rate @ Std Conditions XORATE WT S Oil Weight Rate @ Std Conditions XWRATE WT S Water Weight Rate @ Std Conditions XGRATE GV S Gas Volume Rate @ Std Conditions XORATE LV S Oil Volume Rate @ Std Conditions XWRATE LV S Water Volulme Rate @ Std Conditions XGRATE WT A Gas Weight Rate @ Actual Conditions XORATE WT A Oil Weight Rate @ Actual Conditions XWRATE WT A Water Weight Rate @ Actual Conditions XGRATE GV A Gas Volume Rate @ Actual Conditions XORATE LV A Oil Volume Rate @ Actual Conditions XWRATE LV A Water Volume Rate @ Actual Conditions XRATE WT S Weight Rate @ Actual Conditions XGL RTE GV A Gas Lift Volume Rate @ Actual Conditions XGL RTE WT A Gas Lift Weight Rate @ Actual Conditions XNODE GLGRAV Gas Lift Gravity XNODE GLDENS Gas Lift Density XGAS MW S Gas Molecular Weight @ Std Conditions XOIL MW S Oil Molecular Weight @ Std Conditions XWAT MW S Water Molecular Weight @ Std Conditions XAVG MW S AVG Molecular Weight @ Std Conditions X

Fluid Type = BlackoilRATE(LV) Standard Liquid Volume Flow Rate X XERATE(LV) Std Liquid Volume Flow Rate Estimate X X

TEMPERATURE Temperature X X PRESSURE Pressure X X EPRESSURE Pressure Estimate X X GOR Gas Oil Ratio X X WATER CUT Water Cut X X GAS VISC Gas Viscosity X OIL VISC Oil Viscosity X WAT VISC Water Viscosity X GAS FRACTION Gas Fraction X LIQ FRACTION Liquid Fraction X GAS DENSITY Gas Density X OIL DENSITY Oil Density X WAT DENSITY Water Density X WOBBE Wobbe Index X GHV Gross Heating Value X TRACE Component Mole Fractions X X GRATE WT S Gas Weight Rate @ Std Conditions X GL RTE GV S Gas Lift Volume Rate @ Std Conditions X GL RTE WT S Gas Lift Weight Rate @ Std Conditions X ORATE WT S Oil Weight Rate @ Std Conditions X WRATE WT S Water Weight Rate @ Std Conditions X

Variable

Available as a

VariableDescription



Define


GRATE GV S Gas Volume Rate @ Std Conditions X ORATE LV S Oil Volume Rate @ Std Conditions X WRATE LV S Water Volume Rate @ Std Conditions X GRATE GV A Gas Volume Rate @ Actual Conditions X ORATE LV A Oil Volume Rate @ Actual Conditions X WRATE LV A Water Volume Rate @ Actual Conditions X GL RTE GV A Gas Lift Volume Rate @ Actual Conditions X GL RTE WT A Gas Lift Weight Rate @ Actual Conditions X NODE GLGRAV Gas Lift Gravity X NODE GLDENS Gas Lift Density X NODE OGRAV Oil Gravity X NODE GGRAV Gas Gravity X NODE WGRAV Water Gravity X

Fluid Type = Condensate (Gas)RATE(GV) Standard Gas Volume Flow Rate X XERATE(GV) Standard Gas Volume Flow Rate Estimate X XTEMPERATURE Temperature X X PRESSURE Pressure X X EPRESSURE Pressure Estimate X X CGR Condensate Gas Ratio X X WGR Water Gas Ratio X X GAS VISC Gas Viscosity X OIL VISC Oil Viscosity X WAT VISC Water Viscosity X GAS FRACTION Gas Fraction X LIQ FRACTION Liquid Fraction X GAS DENSITY Gas Density X COND DENSITY Condensate Density XWAT DENSITY Water Density XWOBBE Wobbe Index XGHV Gross Heating Value XTRACE Component Mole Fractions X XGRATE WT S Gas Weight Rate @ Std Conditions X ORATE WT S Oil Weight Rate @ Std Conditions X WRATE WT S Water Weight Rate @ Std Conditions X GRATE GV S Gas Volume Rate @ Std Conditions X ORATE LV S Oil Volume Rate @ Std Conditions X WRATE LV S Water Volume Rate @ Std Conditions X GRATE GV A Gas Volume Rate @ Actual Conditions X ORATE LV A Oil Volume Rate @ Actual Conditions X WRATE LV A Water Volume Rate @ Actual Conditions X NODE GGRAV Gas Gravity X NODE WGRAV Water Gravity X NODE CGRAV Condensate Gravity X

Variable

Available as a

VariableDescription



Define


Fluid Type = SteamRATE(WT) Weight Flow Rate X XERATE(WT) Weight Flow Rate Estimate X XTEMPERATURE Temperature X X PRESSURE Pressure X X EPRESSURE Pressure Estimate X XQUALITY Steam Quality (wt) X X GAS VISC Gas Viscosity X WAT VISC Water Viscosity X GAS FRACTION Gas Fraction X LIQ FRACTION Liquid Fraction X GAS DENSITY Gas Density X WAT DENSITY Water Density XGRATE WT S Gas Weight Rate @ Std Conditions X WRATE WT S Water Weight Rate @ Std Conditions X GRATE GV S Gas Volume Rate @ Std Conditions X WRATE LV S Water Volume Rate @ Std Conditions X GRATE GV A Gas Volume Rate @ Actual Conditions X WRATE LV A Water Volume Rate @ Actual Conditions X NODE WGRAV Water Gravity X

Fluid Type = Gas RATE(GV) Standard Gas Volume Flow Rate X X ERATE(GV) Standard Gas Volume Flow Rate Estimate X X TEMPERATURE Temperature X X PRESSURE Pressure X X EPRESSURE Pressure Estimate X X GAS VISC Gas Viscosity X GAS DENSITY Gas Density X WOBBE Wobbe Index X GHV Gross Heating Value X TRACE Component Mole Fractions X X GRATE WT S Gas Weight Rate @ Std Conditions X GRATE GV S Gas Volume Rate @ Std Conditions X GRATE GV A Gas Volume Rate @ Actual Conditions X NODE GGRAV Gas Gravity X

Fluid Type = LiquidRATE(LV) Standard Liquid Volume Flow Rate X XERATE(LV) Std Liquid Volume Flow Rate Estimate X X

TEMPERATURE Temperature X X PRESSURE Pressure X X EPRESSURE Pressure Estimate X X OIL VISC Oil Viscosity X OIL DENSITY Oil Density X ORATE WT S Oil Weight Rate @ Std Conditions X ORATE LV S Oil Volume Rate @ Std Conditions X

Variable

Available as a

VariableDescription



Define


Sinks

Table 4-55b: SINK (CCLASS = SINK) – Case Study, Time stepping, Optimization & Calculator Variables

ORATE LV A Oil Volume Rate @ Actual Conditions X NODE OGRAV Oil Gravity X

Variable

Available as a

VariableDescription



Define

Fluid Type = CompositionalRATE(M) Molar Flow Rate X XRATE(WT) Weight Flow Rate X XRATE(LV) Standard Liquid Volume Flow Rate X XRATE(GV) Standard Gas Volume Flow Rate X XERATE(WT) Weight Flow Rate Estimate X XERATE(LV) Std Liquid Volume Flow Rate Estimate X XERATE(GV) Standard Gas Volume Flow Rate Estimate X XTEMPERATURE Temperature XPRESSURE Pressure X XEPRESSURE Pressure Estimate X XGAS VISC Gas Viscosity XOIL VISC Oil Viscosity XWAT VISC Water Viscosity XGAS FRACTION Gas Fraction XLIQ FRACTION Liquid Fraction XGAS MW Gas Molecular Weight XOIL MW Oil Molecular Weight XWAT MW Water Molecular Weight XAVG MW Average Molecular Weight XTOTAL ENTH Total Enthalpy XGAS DENSITY Gas Density XOIL DENSITY Oil Density XWAT DENSITY Water Density XXLFEED(M) Component Mole Fractions XXLFEED(WT) Component Weight Fractions XWOBBE Wobbe Index XGHV Gross Heating Value XGRATE WT S Gas Weight Rate @ Std Conditions XGL RTE GV S Gas Lift Volume Rate @ Std Conditions XGL RTE WT S Gas Lift Weight Rate @ Std Conditions XORATE WT S Oil Weight Rate @ Std Conditions XWRATE WT S Water Weight Rate @ Std Conditions XGRATE GV S Gas Volume Rate @ Std Conditions X

Variable

Available as a

VariableDescription



Define


ORATE LV S Oil Volume Rate @ Std Conditions XWRATE LV S Water Volulme Rate @ Std Conditions XGRATE WT A Gas Weight Rate @ Actual Conditions XORATE WT A Oil Weight Rate @ Actual Conditions XWRATE WT A Water Weight Rate @ Actual Conditions XGRATE GV A Gas Volume Rate @ Actual Conditions XORATE LV A Oil Volume Rate @ Actual Conditions XWRATE LV A Water Volume Rate @ Actual Conditions XRATE WT S Weight Rate @ Actual Conditions XGL RTE GV A Gas Lift Volume Rate @ Actual Conditions XGL RTE WT A Gas Lift Weight Rate @ Actual Conditions XNODE GLGRAV Gas Lift Gravity XNODE GLDENS Gas Lift Density XGAS MW S Gas Molecular Weight @ Std Conditions XOIL MW S Oil Molecular Weight @ Std Conditions XWAT MW S Water Molecular Weight @ Std Conditions XAVG MW S AVG Molecular Weight @ Std Conditions X

Fluid Type = BlackoilRATE(LV) Standard Liquid Volume Flow Rate X XERATE(LV) Std Liquid Volume Flow Rate Estimate X X

TEMPERATURE Temperature X PRESSURE Pressure X X EPRESSURE Pressure Estimate X X GOR Gas Oil Ratio X WATER CUT Water Cut X GAS VISC Gas Viscosity X OIL VISC Oil Viscosity X WAT VISC Water Viscosity X GAS FRACTION Gas Fraction X LIQ FRACTION Liquid Fraction X GAS DENSITY Gas Density X OIL DENSITY Oil Density X WAT DENSITY Water Density X WOBBE Wobbe Index X GHV Gross Heating Value X TRACE Component Mole Fractions X GRATE WT S Gas Weight Rate @ Std Conditions X GL RTE GV S Gas Lift Volume Rate @ Std Conditions X GL RTE WT S Gas Lift Weight Rate @ Std Conditions X ORATE WT S Oil Weight Rate @ Std Conditions X WRATE WT S Water Weight Rate @ Std Conditions X GRATE GV S Gas Volume Rate @ Std Conditions X ORATE LV S Oil Volume Rate @ Std Conditions X WRATE LV S Water Volume Rate @ Std Conditions X GRATE GV A Gas Volume Rate @ Actual Conditions X

Variable

Available as a

VariableDescription



Define


ORATE LV A Oil Volume Rate @ Actual Conditions X WRATE LV A Water Volume Rate @ Actual Conditions X GL RTE GV A Gas Lift Volume Rate @ Actual Conditions X GL RTE WT A Gas Lift Weight Rate @ Actual Conditions X NODE GLGRAV Gas Lift Density X NODE OGRAV Oil Gravity X NODE GGRAV Gas Gravity X NODE WGRAV Water Gravity X

Fluid Type = Condensate (Gas)RATE(GV) Standard Gas Volume Flow Rate X XERATE(GV) Standard Gas Volume Flow Rate Estimate X XTEMPERATURE Temperature X PRESSURE Pressure X X EPRESSURE Pressure Estimate X X CGR Condensate Gas Ratio X WGR Water Gas Ratio X GAS VISC Gas Viscosity X OIL VISC Oil Viscosity X WAT VISC Water Viscosity X GAS FRACTION Gas Fraction X LIQ FRACTION Liquid Fraction X GAS DENSITY Gas Density X COND DENSITY Condensate Density XWAT DENSITY Water Density XWOBBE Wobbe Index XGHV Gross Heating Value XTRACE Component Mole Fractions XGRATE WT S Gas Weight Rate @ Std Conditions X ORATE WT S Oil Weight Rate @ Std Conditions X WRATE WT S Water Weight Rate @ Std Conditions X GRATE GV S Gas Volume Rate @ Std Conditions X ORATE LV S Oil Volume Rate @ Std Conditions X WRATE LV S Water Volume Rate @ Std Conditions X GRATE GV A Gas Volume Rate @ Actual Conditions X ORATE LV A Oil Volume Rate @ Actual Conditions X WRATE LV A Water Volume Rate @ Actual Conditions X NODE GGRAV Gas Gravity X NODE WGRAV Water Gravity X NODE CGRAV Condensate Gravity X

Variable

Available as a

VariableDescription



Define


Fluid Type = SteamRATE(WT) Weight Flow Rate X XERATE(WT) Weight Flow Rate Estimate X XTEMPERATURE Temperature X PRESSURE Pressure X X EPRESSURE Pressure Estimate X XQUALITY Steam Quality (wt) X GAS VISC Gas Viscosity X WAT VISC Water Viscosity X GAS FRACTION Gas Fraction X LIQ FRACTION Liquid Fraction X GAS DENSITY Gas Density X WAT DENSITY Water Density XGRATE WT S Gas Weight Rate @ Std Conditions X WRATE WT S Water Weight Rate @ Std Conditions X GRATE GV S Gas Volume Rate @ Std Conditions X WRATE LV S Water Volume Rate @ Std Conditions X GRATE GV A Gas Volume Rate @ Actual Conditions X WRATE LV A Water Volume Rate @ Actual Conditions X NODE WGRAV Water Gravity X

Fluid Type = Gas RATE(GV) Standard Gas Volume Flow Rate X X ERATE(GV) Standard Gas Volume Flow Rate Estimate X X TEMPERATURE Temperature PRESSURE Pressure X X EPRESSURE Pressure Estimate X X GAS VISC Gas Viscosity X GAS DENSITY Gas Density X WOBBE Wobbe Index X GHV Gross Heating Value X TRACE Component Mole Fractions X GRATE WT S Gas Weight Rate @ Std Conditions X GRATE GV S Gas Volume Rate @ Std Conditions X GRATE GV A Gas Volume Rate @ Actual Conditions X NODE GGRAV Gas Gravity X

Fluid Type = LiquidRATE(LV) Standard Liquid Volume Flow Rate X XERATE(LV) Std Liquid Volume Flow Rate Estimate X X

TEMPERATURE Temperature PRESSURE Pressure X X EPRESSURE Pressure Estimate X X OIL VISC Oil Viscosity X OIL DENSITY Oil Density X ORATE WT S Oil Weight Rate @ Std Conditions X

Variable

Available as a

VariableDescription



Define


Junctions

Table 4-55c: JUNCTION (CCLASS = JUNCTION) – Case Study, Time stepping, Optimization & Calculator Variables

ORATE LV S Oil Volume Rate @ Std Conditions X ORATE LV A Oil Volume Rate @ Actual Conditions X NODE OGRAV Oil Gravity X

Variable

Available as a

VariableDescription



Define

Fluid Type = CompositionalRATE(M) Molar Flow Rate XRATE(WT) Weight Flow Rate XRATE(LV) Standard Liquid Volume Flow Rate XRATE(GV) Standard Gas Volume Flow Rate XTEMPERATURE Temperature XPRESSURE Pressure XEPRESSURE Pressure Estimate X XGAS VISC Gas Viscosity XOIL VISC Oil Viscosity XWAT VISC Water Viscosity XGAS FRACTION Gas Fraction XLIQ FRACTION Liquid Fraction XGAS MW Gas Molecular Weight XOIL MW Oil Molecular Weight XWAT MW Water Molecular Weight XAVG MW Average Molecular Weight XTOTAL ENTH Total Enthalpy XGAS DENSITY Gas Density XOIL DENSITY Oil Density XWAT DENSITY Water Density XXLFEED(M) Component Mole Fractions XXLFEED(WT) Component Weight Fractions XWOBBE Wobbe Index XGHV Gross Heating Value XGRATE WT S Gas Weight Rate @ Std Conditions XGL RTE GV S Gas Lift Volume Rate @ Std Conditions XGL RTE WT S Gas Lift Weight Rate @ Std Conditions XORATE WT S Oil Weight Rate @ Std Conditions XWRATE WT S Water Weight Rate @ Std Conditions XGRATE GV S Gas Volume Rate @ Std Conditions XORATE LV S Oil Volume Rate @ Std Conditions XWRATE LV S Water Volulme Rate @ Std Conditions X

Variable

Available as a

VariableDescription



Define


GRATE WT A Gas Weight Rate @ Actual Conditions XORATE WT A Oil Weight Rate @ Actual Conditions XWRATE WT A Water Weight Rate @ Actual Conditions XGRATE GV A Gas Volume Rate @ Actual Conditions XORATE LV A Oil Volume Rate @ Actual Conditions XWRATE LV A Water Volume Rate @ Actual Conditions XRATE WT S Weight Rate @ Actual Conditions XGL RTE GV A Gas Lift Volume Rate @ Actual Conditions XGL RTE WT A Gas Lift Weight Rate @ Actual Conditions XNODE GLGRAV Gas Lift Gravity XNODE GLDENS Gas Lift Density XGAS MW S Gas Molecular Weight @ Std Conditions XOIL MW S Oil Molecular Weight @ Std Conditions XWAT MW S Water Molecular Weight @ Std Conditions XAVG MW S AVG Molecular Weight @ Std Conditions X

Fluid Type = BlackoilRATE(LV) Standard Liquid Volume Flow Rate X

TEMPERATURE Temperature X PRESSURE Pressure X EPRESSURE Pressure Estimate X X GOR Gas Oil Ratio X WATER CUT Water Cut X GAS VISC Gas Viscosity X OIL VISC Oil Viscosity X WAT VISC Water Viscosity X GAS FRACTION Gas Fraction X LIQ FRACTION Liquid Fraction X GAS DENSITY Gas Density X OIL DENSITY Oil Density X WAT DENSITY Water Density X WOBBE Wobbe Index X GHV Gross Heating Value X TRACE Component Mole Fractions X GRATE WT S Gas Weight Rate @ Std Conditions X GL RTE GV S Gas Lift Volume Rate @ Std Conditions X GL RTE WT S Gas Lift Weight Rate @ Std Conditions X ORATE WT S Oil Weight Rate @ Std Conditions X WRATE WT S Water Weight Rate @ Std Conditions X GRATE GV S Gas Volume Rate @ Std Conditions X ORATE LV S Oil Volume Rate @ Std Conditions X WRATE LV S Water Volume Rate @ Std Conditions X GRATE GV A Gas Volume Rate @ Actual Conditions X ORATE LV A Oil Volume Rate @ Actual Conditions X WRATE LV A Water Volume Rate @ Actual Conditions X GL RTE GV A Gas Lift Volume Rate @ Actual Conditions X GL RTE WT A Gas Lift Weight Rate @ Actual Conditions X

Variable

Available as a

VariableDescription



Define


NODE GLGRAV Gas Lift Gravity X NODE GLDENS Gas Lift Density X NODE OGRAV Oil Gravity X NODE GGRAV Gas Gravity X NODE WGRAV Water Gravity X

Fluid Type = Condensate (Gas)RATE(GV) Standard Gas Volume Flow Rate XTEMPERATURE Temperature X PRESSURE Pressure X EPRESSURE Pressure Estimate X X CGR Condensate Gas Ratio X WGR Water Gas Ratio X GAS VISC Gas Viscosity X OIL VISC Oil Viscosity X WAT VISC Water Viscosity X GAS FRACTION Gas Fraction X LIQ FRACTION Liquid Fraction X GAS DENSITY Gas Density X COND DENSITY Condensate Density XWAT DENSITY Water Density XWOBBE Wobbe Index XGHV Gross Heating Value XTRACE Component Mole Fractions XGRATE WT S Gas Weight Rate @ Std Conditions X ORATE WT S Oil Weight Rate @ Std Conditions X WRATE WT S Water Weight Rate @ Std Conditions X GRATE GV S Gas Volume Rate @ Std Conditions X ORATE LV S Oil Volume Rate @ Std Conditions X WRATE LV S Water Volume Rate @ Std Conditions X GRATE GV A Gas Volume Rate @ Actual Conditions X ORATE LV A Oil Volume Rate @ Actual Conditions X WRATE LV A Water Volume Rate @ Actual Conditions X NODE GGRAV Gas Gravity X NODE WGRAV Water Gravity X NODE CGRAV Condensate Gravity X

Fluid Type = SteamRATE(WT) Weight Flow Rate XTEMPERATURE Temperature X PRESSURE Pressure X EPRESSURE Pressure Estimate X XQUALITY Steam Quality (wt) X GAS VISC Gas Viscosity X WAT VISC Water Viscosity X GAS FRACTION Gas Fraction X LIQ FRACTION Liquid Fraction X

Variable

Available as a

VariableDescription



Define


GAS DENSITY Gas Density X WAT DENSITY Water Density XGRATE WT S Gas Weight Rate @ Std Conditions X WRATE WT S Water Weight Rate @ Std Conditions X GRATE GV S Gas Volume Rate @ Std Conditions X WRATE LV S Water Volume Rate @ Std Conditions X GRATE GV A Gas Volume Rate @ Actual Conditions X WRATE LV A Water Volume Rate @ Actual Conditions X NODE WGRAV Water Gravity X

Fluid Type = Gas RATE(GV) Standard Gas Volume Flow Rate X TEMPERATURE Temperature X PRESSURE Pressure X EPRESSURE Pressure Estimate X X GAS VISC Gas Viscosity X GAS DENSITY Gas Density X WOBBE Wobbe Index X GHV Gross Heating Value X TRACE Component Mole Fractions X GRATE WT S Gas Weight Rate @ Std Conditions X GRATE GV S Gas Volume Rate @ Std Conditions X GRATE GV A Gas Volume Rate @ Actual Conditions X NODE GGRAV Gas Gravity X

Fluid Type = LiquidRATE(LV) Standard Liquid Volume Flow Rate X

TEMPERATURE Temperature X PRESSURE Pressure X EPRESSURE Pressure Estimate X X OIL VISC Oil Viscosity X OIL DENSITY Oil Density X ORATE WT S Oil Weight Rate @ Std Conditions X ORATE LV S Oil Volume Rate @ Std Conditions X ORATE LV A Oil Volume Rate @ Actual Conditions X NODE OGRAV Oil Gravity X

Variable

Available as a

VariableDescription



Define


Pipe

Table 4-55d: PIPE (CCLASS = PIPE) – Case Study, Time Stepping, Optimization, & Calculator Variables

* Flow Correlation is not supported for Time Stepping and Optimization.

Available as a

Variable VariableDescription



Define

PIPE ID Pipe Inside Diameter X XPIPE LENGTH Pipe Length X XPIPE ELEV Pipe Elevation X XROUGHNESS Absolute Wall Roughness X XRELROUGHNESS Relative Wall Roughness X XFLOW EFF Flow Efficiency X XPLM UPHILL Palmer Uphill Liquid Holdup Factor X XPLM DOWNHILL Palmer Downhill Liquid Holdup Factor X XFLOW CODE Flow Correlation* X XU PIPE U-Value X XAMBIENT TEMP Ambient Temperature X XPIPE THICKNS Pipe Wall Thickness X XPIPE COND Pipe Wall Conductivity X XH INSIDE Inside Film Heat Transfer Coefficient X XH OUTSIDE Outside Film Heat Transfer Coefficient X XTHICKNS INS Insulation Thickness X XINS COND Insulation Conductivity X XBURIAL DEPTH Burial Depth X XSOIL COND Soil Conductivity X XPIPE DP Pressure Change XOUTLET PRES Outlet Pressure XOUTLET TEMP Outlet Temperature XTOT PIPE LNG Total Pipe Length X XTOT PIPE ELV Total Pipe Elevation X X


Tubing

Table 4-55e: TUBING (CCLASS = TUBI) – Case Study, Time Stepping, Optimization, & Calculator Variables:


Available as a




Define

TUBE ID Inside Diameter X XTVD (DEPTH) Set Vert Depth to Tubing Btm X XMWD (LENGTH) Set Meas Wireline Depth to Tubing Btm X XMWD AND TVD Scaled MWD AND TVD Depths X XCTVD(TO TOP) Vertical Depth to Tubing Top XCTVD(DEPTH) Vertical Depth to Tubing Btm XCMWD(TO TOP) Measured Wireline Depth to Tubing Top XCMWD(LENGTH) Measured Wireline Depth to Tubing Btm XROUGHNESS Absolute Wall Roughness X XRELROUGHNESS Relative Wall Roughness X XFLOW EFF Flow Efficiency X XU TUBE U-Value X XGEO TGRAD Geothermal Temperature Gradient X XFLOW CODE Flow Correlation* X XPLM UPHILL Palmer Uphill Liquid Holdup Factor X XPLM DOWNHILL Palmer Downhill Liquid Holdup Factor X XBTM HOLE P Bottom Hole Pressure XTUBING DP Pressure Change XOUTLET PRES Outlet Pressure XOUTLET TEMP Outlet Temperature X


Annulus

Table 4-55f: Annulus (CCLASS = ANNU) – Case Study, Time Stepping, Optimization, & Calculator Variables:


Available as a




Define

ANNULUS ID Annulus Casing ID X XOD TUBE Annulus Tubing OD X XTVD (DEPTH) Set Vert Depth to Annulus Btm X XMWD (LENGTH) Set Meas Wireline Depth to

Annulus BtmX X

MWD AND TVD MWD with Scaled True Vertical Depth

X X

CTVD(TO TOP) Vertical Depth to Annulus Top XCTVD(DEPTH) Vertical Depth to Annulus Btm XCMWD(TO TOP) Measured Wireline Depth to

Annulus TopX

CMWD(LENGTH) Measured Wireline Depth to Annulus Btm

X

ROUGHNESS Absolute Wall Roughness X XRELROUGHNESS Relative Wall Roughness X XFLOW EFF Flow Efficiency X XU ANNULUS U-Value X XFLOW CODE Flow Correlation* X XPLM UPHILL Palmer Uphill Liquid Holdup

FactorX X

PLM DOWNHILL Palmer Downhill Liquid Holdup Factor

X X

GEO TGRAD Geothermal Temperature Gradient

X X

BTM HOLE P Bottom Hole Pressure XANNULUS DP Annulus Pressure Change XOUTLET PRES Outlet Pressure XOUTLET TEMP Outlet Temperature X


Compressors

Table 4-55g: COMPRESSOR (CCLASS = COMPR) – Case Study, Time Stepping, Optimization, & Calculator Variables:

Pumps

Table 4-55h: PUMP (CCLASS = PUMP), ESP (CCLASS = ESP PUMP) – Case Study, Time Stepping, Optimization, & Calculator Variables:

Available as a



Objective Constraint Decision

SET POWER Power X XSET PRESSURE Pressure X XMAX POWER Maximum Power X XMAX PRESSURE Maximum Pressure X XSTAGES Number of Stages X XCOMPR EFF Compressor Efficiency X XRPM RPM X XMAX RPM Maximum RPM X XCOMPR DP Pressure Change XOUTLET PRES Outlet Pressure XOUTLET TEMP Outlet Temperature XREQ POWER Required Power X

Variable

Description

Available as a

Variable Parameter Change Decision

Objective Constraint Define

SET POWER Power X XSET PRESSURE Pressure X XMAX POWER Maximum Power X XMAX PRESSURE Maximum Pressure X XSTAGES Number of Stages X XMEAS LENGTH Set Meas Wireline Depth to Pump Btm X XVERT DEPTH Set Vert Depth to Pump Btm X XPUMP EFF Pump Efficiency X XRPM RPM X XMAX RPM Maximum RPM X XOUTLET PRES Outlet Pressure XOUTLET TEMP Outlet Temperature XREQ POWER Required Power XPUMP DP Pressure Change XCTVD(TO TOP) Vertical Depth to Pump Top XCTVD(DEPTH) Vertical Depth to Pump Btm XCMWD(TO TOP) Measured Wireline Depth to Pump Top XCMWD(LENGTH) Measured Wireline Depth to Pump Btm XDEPTH CHANGE Pump Vertical Elevation Change XPINTAKE Pump Intake Pressure XFLD OVER PMP Submergence Depth (Fluid Over Pump) X XCSG HEAD PRE Casing Head Pressure X XGAS INGESTED Gas ingested by Pump X X


Heater

Table 4-55i: HEATER (CCLASS = HEAT) – Case Study, Time Stepping, Optimization, & Calculator Variables:

Cooler

Table 4-55j: COOLER (CCLASS = COOL) – Case Study, Time Stepping, Optimization, & Calculator Variables:

Available as a




Define

SET DUTY Duty X X

MAX DUTY Maximum Duty X X

SET TEMP OUT Set Outlet Temperature X X

MAX TEMP OUT Maximum Outlet Temperature

X X

HEATER DP Pressure Change X X

COEF Pressure Drop Correlation Coefficient

X X

EXP Pressure Drop Correlation Exponent

X X

REQ DUTY Required Duty XOUTLET PRES Outlet Pressure XOUTLET TEMP Outlet Temperature X

Available as a




Define

SET DUTY Duty X X

MAX DUTY Maximum Duty X X

SET TEMP OUT Set Outlet Temperature X X

MIN TEMP OUT Minimum Outlet Temperature

X X

COOLER DP Pressure Change X X

COEF Pressure Drop Correlation Coefficient

X X

EXP Pressure Drop Correlation Exponent

X X

REQ DUTY Required Duty XOUTLET PRES Outlet Pressure XOUTLET TEMP Outlet Temperature X


Completion

Table 4-55k: COMPLETION (CCLASS = COMPL) – Case Study, Time Stepping, Optimization, & Calculator Variables:

Gaslift Valves

Table 4-55l: GAS LIFT VALVE (CCLASS = GAVL) – Case Study, Time Stepping, Optimization, & Calculator Variables:

Chokes

Table 4-55m: CHOKE (CCLASS = CHOK) – Case Study, Time Stepping, Optimization, & Calculator Variables:

Available as a




Define

TUNNEL LNGTH Tunnel Length X X

PERF DIA Perforation Diameter X X

SHOT DENSITY Shot Density X X

THICKNESS Thickness X X

PENE Penetration X X

LENGTH Perforation Length X X

PERM-CRSH ZN Crushed Zone Permeability X X

PERM-RESERV Reservoir Zone Permeability X X

COMPL DP Pressure Change XOUTLET PRES Outlet Pressure XOUTLET TEMP Outlet Temperature X

PERM-GRAVEL Gravel Permeability X X

Available as a




Define

GV RATE Lift Gas Rate X X

DISSOLVE Soluble Dissolved Lift Gas (vol basis) X X

OUTLET PRES Outlet Pressure X

OUTLET TEMP Outlet Temperature X

Available as a




Define

CHOKE ID Inside Diameter X X

SET PRES OUT Set Outlet Pressure X X

SET PRES IN Set Inlet Pressure X X


Separators

Table 4-55n: SEPARATOR (CCLASS = SEPA) – Case Study, Time Stepping, Optimization, & Calculator Variables:

CHK RATE(WT) Weight Flow Rate X X

CHK RATE(LV) Liquid Volume Flow Rate X X

CHK RATE(GV) Gas Volume Flow Rate X X

COEF Resistance Coefficient X X

COEFF A Gilbert Coefficient A X X

COEFF B Gilbert Coefficient B X X

COEFF C Gilbert Coefficient C X X

CRIT PRATIO Critical Pressure Ratio X X

CHOKE DP Pressure Change X



Available as a




Define

Fluid Type: Compositional

SET GAS RATE Set Gas Rate X X

SET OIL RATE Set Oil Rate X X

SET H2O RATE Set Water Rate X X

GAS PERCENT Gas Percent X X

OIL PERCENT Oil Percent X X

H2O PERCENT Water Percent X X



GAS RATE Removed Gas GV Rate @ Act Conditions X X

LIQ RATE Removed Liquid LV Rate @ Act Conditions X X

OIL RATE Removed Oil LV Rate @ Act Conditions X X

H2O RATE Removed Water LV Rate @ Act Conditions X X

GAS RATE(WT) Calculated Gas Mass Rate Removed X X

OIL RATE(WT) Calculated Oil Mass Rate Removed X X

H2O RATE(WT) Calculated Water Mass Rate Removed X X

Available as a




Define


Regulators

Table 4-55o: REGULATOR (CCLASS = REGU) – Case Study, Time Stepping, Optimization, & Calculator Variables:

Fluid Type: Blackoil

SET GAS RATE Set Gas Rate X X


GAS PERCENT Gas Percent X X




GAS RATE Removed Gas GV Rate @ Act Conditions X X


GAS RATE(WT) Calculated Gas Mass Rate Removed X X


Fluid Type: Condensate (Gas)

SET OIL RATE Set Oil Rate X X

COND RATE Condensate Rate X X


OIL PERCENT Oil Percent X X

COND PERC Condensate Percent X X




LIQ RATE Removed Liquid LV Rate @ Act Conditions X X

OIL RATE Removed Oil LV Rate @ Act Conditions X X


OIL RATE(WT) Calculated Oil Mass Rate Removed X X


Available as a




Define

REG PRESSURE Set Outlet Pressure X X

REG PSUCTION Set Inlet Pressure X X

REG RATE(WT) Total Weight Flow Rate X X

REG RATE(LV) Total Liquid Flow Rate X X

Available as a




Define


Expanders

Table 4-55p: EXPANDER (CCLASS = EXPAND) – Case Study, Time Stepping, Optimization, & Calculator Variables:

Valves

Table 4-55q: VALVE (CCLASS = VALV) – Case Study, Time Stepping, Optimization, & Calculator Variables:

REG RATE(GV) Total Gas Volume Flow Rate X X

REG DP Pressure Change X



Available as a




Define



Available as a




Define

VALVE DP Pressure Change X



VALVE ID IN Inside Diameter at Inlet X X

VALVE ID OUT Inside Diameter at Outlet X X

VALVE K Resistance Coefficient X X

VALVE KMUL K-Value Multiplier X X

VALVE ANGLE Angle X X

Available as a




Define


Injection

Table 4-55r: INJECTION (CCLASS = INJE) – Case Study, Time Stepping, Optimization, & Calculator Variables:

DPDT Device

Table 4-55s: DPDT Device (CCLASS = DPDT) – Case Study, Time Stepping, Optimization, & Calculator Variables:

Available as a




Define

SET INJ PRES Set Injection Pressure X X

SET INJ TEMP Set Injection Temperature X X

INJ TEMP Calculated Injection Temperature X

INJ PRES Calculated Injection Pressure X

INJECT DP Pressure Change X



Available as a




Define



DP IN DPDT Pressure Difference X

DT IN DPDT Temperature Difference X

Q CV PT VAL Flowrates for Curve 1 X X

DP CV PT VAL Pressure Differences for Curve 1 X X

DT CV PT VAL Temperature Differences for Curve 1 X X

Q CV2 PT VL Flowrates for Curve 2 X X

DP CV2 PT VL Pressure Differences for Curve 2 X X

DT CV2 PT VL Temperature Differences for Curve 2 X X











MCOMP

Table 4-55t: MULTICHANGE COMPRESSOR (CCLASS = MCOMP) – Case Study, Time Stepping, Optimization, & Calculator Variables:

Bend

Table 4-55u: BEND (CCLASS = BEND) – Case Study, Time Stepping, Optimization, & Calculator Variables:

Available as a




Define

SET POWER Power X X

MAX POWER Maximum Power X X

W MAX POWER Warn Maximum Power X X

SET PRES IN Set Inlet Pressure X X

SET PRES OUT Set Outlet Pressure X X

MAX PRES OUT Warn Max Outlet Pressure X X

POUT STG Stage Outlet Pressure X X

W MAX TEMP Warn Maximum Temperature X X

TEMP STG Stage Outlet Temperature X X

DUTY STG Stage Duty X X

DP STG Stage Pressure Change X X

STG ADIA EFF Stage Adiabatic Efficiency X X

STG POLY EFF Stage Polytropic Efficiency X X

COMPR DP Pressure Change X



REQ POWER Required Power X

REQ DUTY Required Duty X

Available as a




Define



BEND ID IN Inside Diameter at Inlet X X

BEND ROVERD Radius/Diameter Ratio X X

BEND ANGLE Angle X X

BEND K Resistance Coefficient X X

BEND KMUL K-Value Multiplier X X

ROUGHNESS Absolute Wall Roughness X X

REL ROUGHNESS Relative Wall Roughness X X


Check Valve

Table 4-55v: CHECK VALVE (CCLASS = CHEC) – Case Study, Time Stepping, Optimization, & Calculator Variables:

CHISOLM LAMB Chisolm Lambda Coef X X

CHISOLM C2 Chisolm C2 Coef X X

Available as a




Define

CHECK ID Check Diameter X X

COEF Discharge Coefficient X X

CHECK DP Pressure Change X



Available as a




Define


Contraction

Table 4-55w: CONTRACTION (CCLASS = CONT) – Case Study, Time Stepping, Optimization, & Calculator Variables:

Entrance

Table 4-55x: ENTRANCE (CCLASS = ENTR) – Case Study, Time Stepping, Optimization, & Calculator Variables:

Exit

Table 4-55y: EXIT (CCLASS = EXIT) – Case Study, Time Stepping, Optimization, & Calculator Variables:

Available as a




Define



CONTR ID IN Inside Diameter at Inlet X X

CONTR ID OUT Inside Diameter at Outlet X X

CONTR ANGLE Contraction Angle X X

CONTR K Resistance Coefficient X X



Available as a




Define



ENTR ID OUT Inside Diameter at Outlet X X

ENTR K Resistance Coefficient X X



Available as a



Objective Constraint Define



EXIT ID OUT Inside Diameter at Outlet X X

EXIT K Resistance Coefficient X X




Expansion

Table 4-55z: EXPANSION (CCLASS = EXPANS) – Case Study, Time Stepping, Optimization, & Calculator Variables:

Nozzle

Table 4-55aa: EXPANSION (CCLASS = EXPANS) – Case Study, Time Stepping, Optimization, & Calculator Variables:

Available as a




Define



EXPNS ID IN Inside Diameter at Inlet X X

EXPNS ID OUT Inside Diameter at Outlet X X

EXPNS ANGLE Expansion Angle X X

EXPNS K Resistance Coefficient X X



Available as a




Define



NOZZLE ID Nozzle Diameter X X

NOZZLE ID IN Inside Diameter at Inlet X X

NOZZLE K Resistance Coefficient X X

NOZZLE CPCV Specific Heat Ratio X X




Orifice

Table 4-55ab: ORIFICE (CCLASS = ORIF) – Case Study, Time Stepping, Optimization, & Calculator Variables:

Tee

Table 4-55ac: TEE (CCLASS = TEE) – Case Study, Time Stepping, Optimization, & Calculator Variables:

Available as a




Define



ORIFICE ID Orifice Diameter X X

ORIFIC ID IN Inside Diameter at Inlet X X

ORIFICE K Resistance Coefficient X X

ORIFICE CPCV Specific Heat Ratio X X



Available as a




Define



TEE ID IN Inside Diameter at Inlet X X

TEE K Resistance Coefficient X X

TEE KMUL K-Value Multiplier X X

ROUGHNESS Absolute Wall Roughness X X

REL ROUGHNESS Relative Wall Roughness X X




IPR

Table 4-55ad: IPR (CCLASS = IPR) – Case Study, Time Stepping, Optimization, & Calculator Variables:

Calculator Unit

Table 4-55ae: CALCULATOR UNIT (CCLASS = CALCULATOR) – Case Study, Time Stepping, Optimization, & Calculator Variables:

Available as a




Define

DP Pressure Change X



PPRES Reservoir Pressure Curve X X

AQCUM Reservoir Cum Production X X

AQOCUM Reservoir Oil Cum Production X X

AQLCUM Reservoir Liquid Cum Production X X

AQGCUM Reservoir Gas Cum Production X X

AQWCUM Reservoir Water Cum Production X X

Available as a




Define

R(0001) Calculator Result R1 X X



















Optimization

Table 4-55af: OPTIMIZATION (CCLASS = OPTIMIZATION) – Case Study, Time Stepping, Optimization, & Calculator Variables:

Objective Parameter

Table 4-55ag: OBJECTIVE PARAMETER (CCLASS = OBJECTIVE) – Case Study, Time Stepping, Optimization, & Calculator Variables:



Available as a




Define

OBJ FUNC Value of Objective Function X

BEST OBJ FNC Best Value for Objective Function X

ITERATION Maximum Number of Iterations X X

DEFPERT Default Relative Perturbation X X

OBJTOL Minimum Relative Change in Objective

X X

VARTOL Minimum Relative Change in Decision Var

X X

DEF ERR TOL Default Error Tolerance X X

DAMPING Number of Cycles with Damping X X

DFACTOR Variable Damping Denominator X X

Available as a




Define

VALUE Current Value of Objective Parameter X

ACTIVE Status of Objective Parameter X X

COEF Coefficient for Objective Parameter X X

TARGET Target for Objective Parameter X X

ERROR Relative Error for Tuning Simulations X X

Available as a




Define


Constraint Variable

Table 4-55ah: CONSTRAINT VARIABLE (CCLASS = CONSTRAINT) – Case Study, Time Stepping, Optimization, & Calculator Variables:

Decision Variable

Table 4-55ai: DECISION VARIABLE (CCLASS = DECISION) – Case Study, Time Stepping, Optimization, & Calculator Variables:

Available as a




Define

VALUE Current Value of Constraint X

ACTIVE Status of Constraint Variable X X

TIME Time for Constraint Change X X

ALOWER Absolute Lower Limit X X

AUPPER Absolute Upper Limit X X

RLOWER Relative Lower Limit X X

RUPPER Relative Upper Limit X X

MLOWER Mechanical Lower Limit X X

MUPPER Mechanical Upper Limit X X

ERROR Relative Error of Constraint X

SHADOW PRICE Shadow Price X

Available as a




Define

VALUE Current Value of Decision Variable X

ACTIVE Status of Decision Variable X X

PERT Relative Perturbation X X

TIME Time for Variable Change X X

ALOWER Absolute Lower Limit X X

AUPPER Absolute Upper Limit X X

RLOWER Relative Lower Limit X X

RUPPER Relative Upper Limit X X

MLOWER Mechanical Lower Limit X X

MUPPER Mechanical Upper Limit X X

CAPT COST Capital Cost for Decision Variable X X

SHADOW PRICE Shadow Price X


PVT Data

Table 4-55aj: PVT DATA (CCLASS = PVTDATA) – Case Study, Time Stepping, Optimization, & Calculator Variables:

Network Data

Table 4-55ak: NETWORK DATA (CCLASS = NETW) – Case Study, Time Stepping, Optimization, & Calculator Variables:

Available as a




Define

OIL GRAVITY Oil Gravity X X

GAS GRAVITY Gas Gravity X X

WATER GRAV Water Gravity X X

COND GRAVITY Condensate Gravity X X

COMP(M) Component Mole Fractions X X

LIQ SHEAT Liquid Specific Heat X X

VISCOSITY Viscosity X X

TEMPERATURE Temperature for Viscosity X X

GAS SHEAT Gas Specific Heat Ratio X X

Available as a




Define

OBJ FUNC Objective Function X

BEST OBJ FNC Best Objective Function X

PROD TIME Production Time X X

CUM PROD Cumulative Production X

PDAMP Pressure Damping X X

QDAMP Flowrate Damping X X

HALVING Interval Damping X X

MAXITER Maximum Number of Iterations X X

PRES TOLER Pressure Tolerance X X

SCALE FACTOR Scale Factor X X

MAX VEL GAS Maximum Gas Velocity X

MAX VEL LIQ Maximum Liquid Velocity X

MAX VSG Maximum Superficial Gas Velocity X

MAX VSL Maximum Superficial Liquid Velocity

X

MAX MIX VEL Maximum Mixture Velocity X

MAX HL Maximum Liquid Holdup X

MIN VEL GAS Minimum Gas Velocity X


LINK

Table 4-55al: LINK (CCLASS = LINK) – Case Study, Time Stepping, Optimization, & Calculator Variables:

MIN VEL LIQ Minimum Liquid Velocity X

MIN VSG Minimum Superficial Gas Velocity X

MIN VSL Minimum Superficial Liquid Velocity

X

MIN MIX VEL Minimum Mixture Velocity X

MIN HL Minimum Liquid Holdup X

NETWORK PIMB Minimum Pressure Imbalance X

STD TEMP Standard Temperature X X

STD PRES Standard Pressure X X

MIN TEMP Minimum Temperature X X

MIN PRES Minimum Pressure X X

MAX TEMP Maximum Temperature X X

MAX PRES Maximum Pressure X X

MAP NREMAP Network Remap Request X X

MAP NINSTAT Network Desired Active Status X X

RATE PERT Rate Perturbation X X

MAP NOUTSTAT Network Actual Active Status X X

Available as a




Define

EFLOW RATE Flow Rate Estimate X X

FLOW RATE Flow Rate X

SET MAX RATE Set Maximum Flow Rate X X

SET MIN RATE Set Minimum Flow Rate X X

I PRES Inlet Pressure X

I TEMP Inlet Temperature X

O PRES Outlet Pressure X

O TEMP Outlet Temperature X

LENG PROFILE Length Profile X

ELEV PROFILE Elevation Profile X

TEMP PROFILE Temperature Profile X

PRES PROFILE Pressure Profile X

HLS PROFILE Slip Holdup Profile X

Available as a




Define


HLNS PROFILE No Slip Holdup Profile X

VELG PROFILE Gas Velocity Profile X

VELL PROFILE Liquid Velocity Profile X

VELM PROFILE Mixture Velocity Profile X

I GRATE WT A Actual Gas Weight Rate @ Inlet X

I ORATE WT A Actual Oil Weight Rate @ Inlet X

I WRATE WT A Actual Water Weight Rate @ Inlet X

I GRATE GV A Actual Gas Volume Rate @ Inlet X

I ORATE LV A Actual Oil Volume Rate @ Inlet X

I WRATE LV A Actual Water Volume Rate @ Inlet X

O GRATE WT A Actual Gas Weight Rate @ Outlet X

O ORATE WT A Actual Oil Weight Rate @ Outlet X

O WRATE WT A Actual Water Weight Rate @ Outlet X

O GRATE GV A Actual Gas Volume Rate @ Outlet X

O ORATE LV A Actual Oil Volume Rate @ Outlet X

O WRATE LV A Actual Water Volume Rate @ Outlet X

I GAS DENS A Actual Gas Density @ Inlet X

I OIL DENS A Actual Oil Density @ Inlet X

I WAT DENS A Actual Water Density @ Inlet X

O GAS DENS A Actual Gas Density @ Outlet X

O OIL DENS A Actual Oil Density @ Outlet X

O WAT DENS A Actual Water Density @ Outlet X

I ENTHALPY Enthalpy @ Inlet X

O ENTHALPY Enthalpy @ Outlet X

MAX VEL GAS Maximum Gas Velocity X

MAX VEL LIQ Maximum Liquid Velocity X

MAX VSG Maximum Superficial Gas Velocity X

MAX VSL Maximum Superficial Liquid Velocity X

MAX MIX VEL Maximum Mixture Velocity X

MAX HL Maximum Liquid Holdup X

MIN VEL GAS Minimum Gas Velocity X

MIN VEL LIQ Minimum Liquid Velocity X

MIN VSG Minimum Superficial Gas Velocity X

MIN VSL Minimum Superficial Liquid Velocity X

MIN MIX VEL Minimum Mixture Velocity X

MIN HL Minimum Liquid Holdup X

GAS HOLDUP A Actual Cumulative Gas Holdup X

Available as a




Define


I GLF DENS A Actual Gas Lift Density @ Inlet X

I GTO DENS A Actual Total Gas Density @ Inlet X

O GLF DENS A Actual Gas Lift Density @ Outlet X

O GTO DENS A Actual Total Gas Density @ Outlet X

LIQ HOLDUP A Actual Cumulative Liquid Holdup X

Available as a




Define


SENSITIVITY ANALYSIS Data Category of Input

Overview

The SENSITIVITY ANALYSIS Data Category of Input allows you to study the overall performance of wells, pipelines and other single link systems as a function of one or two parameters (or combinations of parameters) in the system. Multiple flow rates and parameter variations can be simulated in a single Sensitivity Analysis run. This category is optional.

Note: Before using this data section please read Nodal Analysis, p. 3-47. In the base case, both SOURCE and SINK pressures must be supplied and the SOURCE RATE must be estimated.

Table 4-56: Sensitivity Category of Input

SENSITIVITY

Introduces the category.


NODE

Mandatory statement. Defines the Solution Node.


SENSITIVITY None p. 189

NODE NAME= or BOTTOMHOLE or SINK p. 189

{DESCRIPTION} INFLOW= or OUTFLOW= p. 190

{INFLOW} CGR()=, COEFFICIENT()=, COMPOSITIONAL()=, DISSOLVE()=, DP()=, DUTY()=, EFF()=, EXP()=, FLOWEFF()=, GOR()=, ID()=, IDANNULUS()=, II()=, NAME=, NODE=, ODTUBING()=, PENETRATION()=, PERCENT()=, PERFD()=, PI()=, POWER()=, PRESSURE()=, QUALITY()=, RATE()=, ROUGHNESS()=, SHOTS()=, STAGES()=, TEMPERATURE()=, TOUT()=, TUNNEL()=, U()=, VOGEL()=, WCUT()=, WGR()=, COMB=MULTI

p. 190

{OUTFLOW} CGR()=, COEFFICIENT()=, COMPOSITIONAL()=, DISSOLVE()=, DP()=, DUTY()=, EFF()=, EXP()=, FLOWEFF()=, GOR()=, ID()=, IDANNULUS()=, II()=, NAME()=, ODTUBING()=, PENETRATION()=, PERCENT()=, PERFD()=, PI()=, POWER()=, PRESSURE()=, QUALITY()=, RATE()=, ROUGHNESS()=, SHOTS()=, STAGES()=, TEMPERATURE()=, TOUT()=, TUNNEL()=, U()=, VOGEL()=, WCUT()=, WGR()=, COMB=MULTI

p. 193

FLOW RATE()= p. 193


Mandatory entries:

Example:NODE NAME=TUB1

DESCRIPTION

Optional statements. Allow you to enter descriptions of the inflow and outflow sensitivity analysis parameters. You need separate DESCRIPTION statements for Inflow and Outflow.


Example:DESC INFLOW=RP2500, RP3000, RP3500DESC OUTFLOW=ID2.0, ID2.5, ID3.0

INFLOW

Optional statement. Enter the details of the Inflow parameter and the values you wish to use in the sensitivity analysis. You must supply either INFLOW or OUTFLOW or both.

The parameters that are accessible to the Sensitivity Analysis are divided into seven categories, as defined in the table below. If you want to define a sensitivity parameter as a group of variables, you may combine up to ten variables within one Category. You may not combine variables in different categories.

NAME= orBOTTOMHOLE orSINK

Enter the name of the node between the Inflow and Outflow sections of the link. If this is the name of a device, the Solution Node is at the inlet of that device. Alternatively, use BOTTOMHOLE to place the Solution Node at the flowing bottomhole of an injection well. Use SINK to locate the Solution Node at the outlet of the last device, in which case the sink pressure can be used as a Sensitivity Parameter.

INFLOW= Descriptions of the Inflow sensitivity parameter sets. Up to five strings of up to twelve characters each, separated by commas. Each string corresponds to an inflow parameter setting. This keyword cannot appear on the same statement as OUTFLOW.

OUTFLOW= Descriptions of the Outflow sensitivity parameter sets. Up to five strings of up to twelve characters each, separated by commas. Each string corresponds to an outflow parameter setting. This keyword cannot appear on the same statement as INFLOW.


Category 1: Source

Category 2: Sink

Category 3: Devices

NODE=or STREAMID of the Source.

NAME= Name of the Source. This is the name that appears on the statement in the base case. To be available to Sensitivity Analysis, the Source must be given a unique name in the base case.

PRESSURE()=PI()=VOGEL()=COEFFICIENT()=EXP=

Enter up to five values of parameter(s) for a SOURCE, separated by commas. You may not use qualifiers other than to change units of measurement. Refer to the Structure Data Category of input for explanations of the keywords.

COMB=MULTI This multiple combination option calculates all possible combinations of up to five specified inflow and/or outflow parameters and performs a sensitivity analysis on all combinations.

NODE=or STREAMID of the Sink.

NAME= Name of the Sink. This is the name that appears on the statement in the base case. To be available to Sensitivity Analysis, the Sink must be given a unique name in the base case.

PRESSURE()=II()=COEFFICIENT()=EXP=

Enter up to five values of parameter(s) for a SINK, separated by commas. You may not use qualifiers other than to change units of measurement. Refer to the Structure Data Category of input for explanations of the keywords.


NAME= Name of the Device. This is the name that appears on the statement in the base case. To be available to Sensitivity Analysis, the Device must be given a unique name in the base case. The NAME entry on this statement must immediately precede the data entries for the corresponding Device.

IDANNULUS()=ODTUBING()=ROUGHNESS()=U()=FLOWEFF=

Enter up to five values of parameter(s) for an ANNULUS, separated by commas. You may not use qualifiers other than to change units of measurement. Refer to the Structure Data Category of input for explanations of the keywords.

COEFFICIENT=ID()=

Enter up to five values of parameter(s) for a CHOKE, separated by commas. You may not use qualifiers other than to change units of measurement. Refer to the Structure Data Category of input for explanations of the keywords.

PENETRATION()=PERFD()=SHOTS()=TUNNEL()=

Enter up to five values of parameter(s) for a COMPLETION, separated by commas. You may not use qualifiers other than to change units of measurement. Refer to the Structure Data Category of input for explanations of the keywords.

DP()=DUTY()=TOUT()=

Enter up to five values of parameter(s) for a HEATER or COOLER, separated by commas. You may not use qualifiers other than to change units of measurement. Refer to the Structure Data Category of input for explanations of the keywords.


Category 4: Non-compositional Source Properties

Category 5: Main Source Composition

Example:INFLOW NAME=PMP1, PRES=250,260,270,280,290

TEMPERATURE()=PRESSURE()=

Enter up to five values of parameter(s) for an INJECTION, separated by commas. You may not use qualifiers other than to change units of measurement. Refer to the Structure Data Category of input for explanations of the keywords.

DISSOLVE=RATE()=

Enter up to five values of parameter(s) for a GLVALVE, separated by commas. You may not use qualifiers other than to change units of measurement. Refer to the Structure Data Category of input for explanations of the keywords.

ID()=ROUGHNESS()=U()=FLOWEFF=

Enter up to five values of parameter(s) for a PIPE, separated by commas. You may not use qualifiers other than to change units of measurement. Refer to the Structure Data Category of input for explanations of the keywords.

EFF=POWER()=PRESSURE()=STAGES=

Enter up to five values of parameter(s) for a COMPRESSOR or PUMP, separated by commas. You may not use qualifiers other than to change units of measurement. Refer to the Structure Data Category of input for explanations of the keywords.

RATE()=PERCENT=

Enter up to five values of parameter(s) for a SEPARATOR, separated by commas. You may not use qualifiers other than to change units of measurement. Refer to the Structure Data Category of input for explanations of the keywords.

ID()=ROUGHNESS()=U()=FLOWEFF=

Enter up to five values of parameter(s) for a TUBING, separated by commas. You may not use qualifiers other than to change units of measurement. Refer to the Structure Data Category of input for explanations of the keywords.


GOR()=WCUT=CGR()=WGR()=QUALITY=

Enter up to five values of PVT parameter(s), separated by commas. You may not use qualifiers other than to change units of measurement. Refer to the Structure Data Category of input for explanations of the keywords.


COMPOSITION()= Enter up to five values of COMPOSITION parameter(s), separated by commas. You may not use qualifiers other than to change the basis. Refer to the Structure Data Category of input for explanations of the keyword.


OUTFLOW

Optional statement. Enter the details of the Outflow parameter and the values you wish to use in the sensitivity analysis. The OUTFLOW statement is formatted exactly the same as the INFLOW statement. See INFLOW above for details. You must supply either INFLOW or OUTFLOW or both.

FLOW

Mandatory statement. Defines the flowrates for which the Sensitivity Analysis is to be performed.

Mandatory entries:

Sensitivity Examples:SENSITIVITY NODE SINK DESC INFLOW=RESP2500,RESP2400,RESP2300,RESP2200,RESP2100 INFLOW NAME=RES, PRES=2500,2400,2300,2200,2100 DESC OUTFLOW=SINK500,SINK400,SINK300,SINK200 OUTFLOW NAME=SNK1, PRES=500,400,300,200 FLOW RATE=1000,2000,3000,4000,5000,5000,7000,8000

In this example, the reservoir pressure is the inflow parameter and the sink pressure is the outflow parameter. In order to use the sink pressure, the Solution Node is defined as SINK rather than NAME=SNK1.

SENSITIVITY NODE NAME=SNK INFLOW NAME=HTR1, DUTY=0,100,150, & NAME=PIP1, U=0.025,0.05,1.5, & NAME=PIP2, U=0.03,0.05,1.5 FLOW RATE=10000,12000,14000,16000,18000,20000

This example has an inflow parameter but no outflow. The inflow parameter is made up of three variables - the heater duty and the heat transfer coefficients of the two pipes.

RATE()= Enter up to ten values of flowrate.

The flow basis is limited based on the fluid type as follows

Blackoil Liquid LV basis

Condensate Gas GV basis

Steam WT basis

Compositional LV, GV, WT basis


PSPLIT Data Category of Input

The PSPLIT Data Category of input allows you to define a phase split table for the preferential phase split at junctions in steam systems. This category must be supplied if the USER model is specified on any JUNCTION statement. Only one table may be defined for all junctions within the steam network.

Table 4-57: PSPLIT Category of Input

PSPLIT

Introduces the category.

TABLE

Mandatory statement. Defines the table for the user defined phase split.

Mandatory entries:

Example:TABLE LIQP=10/20/30/40/50, GASR=10000,20000, & GASP=88,78,67,57,46/ 87,77,66,56,46


PSPLIT None p. 194

TABLE LIQP=liquid %/...,GASR=gas Reynolds No./..., GASP=gas %,gas %/... p. 194

LIQP= Up to 10 liquid weight percent values for the stream entering the junction, separated by the slash (/) character.

GASR= Up to 10 values for gas Reynolds Number for the stream entering the junction, separated by the slash (/) character.

GASP= Up to 10 sets of up to 10 gas weight percent values for the stream leaving the junction and entering the outflowing link which has the smaller pipe inside diameter for the first pipe in the link. The remainder of the flow goes into the other link.

Each set must have the same number of entries, separated by commas, as the number of LIQP values entered. There must be the same number of sets, separated by the slash (/) character, as the number of GASR values entered.


User-Defined DP Correlations

PIPEPHASE makes it possible to incorporate up to four user-supplied pressure drop correlation methods: two for pipes and two for well flow devices (tubings and annulus). The user methods may be designed for single or multiphase fluid flow and may be used in the same simulation input as PIPEPHASE supplied methods.

The user-written methods are selected in the same manner as the PIPEPHASE supplied methods. The FCODE statement in General Data may be used to set user methods as system defaults (see the General Data Category of input) or the user methods may be individually selected on the PIPE statement via the FCODE keyword. User methods are selected with the method codes UDP1 and UDP2.

User-defined DP correlations must be written in FORTRAN 77 and follow the naming and interface conventions described in this category. The subroutines are compiled with and linked to the PIPEPHASE program, replacing dummy subroutines with the same names.

The mechanics of program compilation and linking varies between computing platforms and are outside the scope of this manual. Your SimSci-Esscor representative can provide you with specific information regarding your particular system configuration.

User-defined correlations may also be used with any of the fittings available in PIPEPHASE. Please contact SimSci-Esscor for support in adding user-defined fitting correlations. It is strongly recommended that user-written subroutines be thoroughly tested before incorporation into PIPEPHASE, since erroneous pressure drops will typically cause solution failure for the iterative calculation methods used in PIPEPHASE. After incorporation into PIPEPHASE, user methods may be tested for reliability by comparison with results from similar PIPEPHASE pressure drop methods.

FORTRAN Standards

FORTRAN 77 coding standards should be observed to avoid any possible conflicts with the PIPEPHASE program, which is written according to these standards.

Standard calls are provided to the PIPEPHASE Moody friction factor function and the PIPEPHASE compositional equilibrium flash subroutine. The latter may be used to determine physical, transport and thermodynamic properties for compositional fluids, as well as the phase splits for these fluids. No user access is provided to the non-compositional fluid property routines used in PIPEPHASE.

Standard naming conventions must be used for the user-written pressure drop correlations. All transfer of information between these subroutines and PIPEPHASE is accomplished through the subroutine argument lists.

The following good coding practices should also be observed when developing user-defined correlations:


• Local variables should always be initialized, since many operating systems do not perform this function.

• As appropriate, user subroutines should test for calculation error conditions, i.e., zero divides, exponent overflows, etc.

• User-computed results should be range tested as needed, with calculated results reset to upper and lower bounds when necessary.

• Efficient coding practices should be observed, since the pressure drop subroutines are called repetitively during the iterative calculations. Inefficient coding will greatly increase the computing time.

• Only one RETURN statement should be used in the subroutine.

• No STOP statements should be used in the subroutine. Control must always be returned to the PIPEPHASE calling routines.

• COMMENT lines should be used generously to simplify later analyses of the sub-routine and to assist SimSci support personnel should assistance be required.

User Subroutine Specifications

For pipes (horizontal device) the following subroutine names must be used:

• HUSER1 - Pressure Drop Correlation Number 1

• HUSER2 - Pressure Drop Correlation Number 2

• VUSER1 - Pressure Drop Correlation Number 1 for vertical devices (TUBINGS, ANNULUS)

• VUSER2 - Pressure Drop Correlation Number 2 for vertical devices (TUBINGS, ANNULUS)

The following argument list must be used for all user pressure drop correlations, where HUSER1or HUSER2 is substituted for NAME, as appropriate:

SUBROUTINE NAME (PIN, TIN, POUT, TOUT, PAVG, TAVG, ICOMP,IFLU, DIR, IBOT, IFLO, IVH, Z, DENO, DENG, DENW, DENL, VISO, VISW, VISL, VISG, SFTO, SFTW, SFTL, QOPIP, QWPIP, GPIP, QTPIP, VELSL, VELSG, VELT, SPGG, SPGO, SPGW, DIAM, AREA, RUFF, AINCL, EFF, DELX, NOACC, DELP, DEN2, DPDLF, DPDLW, NREG, HL, CMW)


The entries DELP, DEN2, DPDLF, DPDLW and NREG must be determined in the user subroutine and passed back to PIPEPHASE. NREG defaults to zero. All other arguments are data passed from the user subroutine. Note that the arguments “Z” and “CMW” are vectors and a local DIMENSION statement should be placed in the user subroutine as follows:

COMMON/TOTBIN/BINRLI(16) DIMENSION Z(50), CMW(50)

The arguments are described below in Table 4-58. Note that the units given below always apply, regardless of the DIMENSION statement units used for the problem. The user-defined DP correlation is called for each calculation segment

Table 4-58: Pressure Drop Subroutine Arguments

Argument Description

PINTINPOUTTOUTPAVGTAVG

Segment Inlet Pressure, psiaSegment Inlet Temperature, °FEstimated Segment Outlet Pressure, psiaEstimated Segment Outlet Temperature, °FSegment Average Pressure, psiaSegment Average Temperature, °F

ICOMP Compositional Flag:0 = Non-compositional1 = Compositional

IFLU Fluid Type Flag: 0 = Single Phase Oil1 = Single Phase Gas2 = Single Phase Liquid3 = Blackoil4 = Condensate5 = Steam or Compositional

IDIR Calculation Direction: -1 = Forward; +1 = Backward

IBOT = 0 when no IPR specified at source= 1 for producing well with IPR specified at source= 2 for injection wells

IVH = 1 for “vertical” devices. The pressure gradient returned is in the vertical direction for vertical devices. Tubing and annuli are considered vertical devices.

for “horizontal” devices. The pressure gradient returned is along the device. Pipes are considered horizontal devices.

IFLO Flow Direction: +1 = FROM to TO nodes, -1 = TO to FROM nodes

Z Composition of Link, mol fractions, vector of 50

DENODENGDENWDENL

Oil Density, lb/ft3

Gas Density, lb/ft3

Water Density, lb/ft3

Total Liquid Density, lb/ft3


VISOVISWVISLVISG

Oil Viscosity, cpWater Viscosity, cpTotal Liquid Viscosity, cpGas Viscosity, cp

SFTOSFTWSFTL

Oil Surface Tension, Dynes/cmWater Surface Tension, Dynes/cmTotal Liquid Surface Tension, Dynes/cm

QOPIPQWPIPQGPIPQTPIP

Oil Rate, ft3/secWater Rate, ft3/secGas Rate, ft3/secTotal Flow Rate, ft3/sec

VELSLVELSGVELT

Superficial Liquid velocity, ft/secSuperficial Gas velocity, ft/secTotal Velocity, ft/sec

SPGGSPGOSPGW

Gas Specific Gravity (Dry Air = 1.0)Oil Specific GravityWater Specific Gravity

DIAM AREA RUFFAINCLEFF DELX NOACC

Pipe Inside Diameter, ftPipe Cross Sectional Area, ft2

Pipe Roughness, inchesPipe Inclination angle, radians (pos. upward flow, neg. downward flow)Flow Efficiency, fractionSegment Length, ftAcceleration term flag: =0 include acceleration term=1 exclude acceleration term

DELP Total Pressure Change across Segment, psi, where a negative sign indicates pressure decrease

DEN2 In-situ Multiphase Density, used for calculating elevation pressure drop, lb/ft3

DPDLF Friction Gradient, psi/ft

DPDLW Elevation Gradient, psi/ft

Argument Description (cont.)


Table 4-59: Flow Regime Code for Output Reports

Saving Data for Output

Certain data, calculated in the DP routine, need to be saved in the BINRL1 array for output. These are listed below in Table 4-60. The BINRL1 array enters the subroutine through the TOTBIN labeled common. If data is not saved properly, this data will be missing in the output report

Table 4-60: Saving Data for Output.

NREG NREG Flow Regime Output Abbreviation

0123456789

10111213

---Single Phase GasSingle Phase SegregatedStratified WavyAnnularIntermittent PlugSlugDistributed BubbleMist Transition

Blank1-PH1-PHSEGRSTRTWAVEANNUINTRPLUGSLUGDISTBUBLMISTTRAN

HL Liquid Holdup

CMW Component Molecular Weights, Vector of 50

Output Variable Description Units

BINRL1(1) SLIP DENSITY (LB/FT3)

BINRL1(2) NO-SLIP DENSITY (LB/FT3)

BINRL1(3) FRICTION VISCOSITY (CENTI-POISE)

BINRL1(4) FRICTION DENSITY (LB/FT3)

BINRL1(5) SUPERFICIAL GAS VELOCITY (FT/S)

BINRL1(6) SUPERFICIAL LIQUID VELOCITY (FT/SEC)

BINRL1(7) FRICTION MIXTURE VELOCITY (FT/SEC)

BINRL1(8) NO-SLIP HOLDUP (DIMENSIONLESS FRACTION)

BINRL1(9) FRICTION REYNOLDS NUMBER (DIMENSIONLESS)

BINRL1(10) FRICTION FACTOR (DIMENSIONLESS)

BINRL1(11) ACCELERATION GRADIENT (PSI/FT)

BINRL1(12) TOTAL PRESSURE GRADIENT (PSI/FT)

BINRL1(13) FRICTION PRESSURE DROP (PSI)

BINRL1(14) ELEVATION PRESSURE DROP (PSI)

BINRL1(15) TOTAL PRESSURE DROP (PSI)

BINRL1(16) FRICTION ID (IN)


PIPEPHASE Flash Routine Interface

An interface is provided to the PIPEPHASE compositional flash routine. Based on a user supplied pressure, temperature, and fluid composition, a variety of physical, transport and thermodynamic properties are computed and returned. The phase split and hold-up data are also returned.

The following standard call may be used from the user subroutine to access the PIPEPHASE compositional flash routine:

CALL PVTCMP (0, UNUM, TEMPIN, PRESIN, ENTH, QUAL, Z, DUM1, DUM2, AMW, & X, Y, W, HLNS, WLR, DENO, DENW, DENG, SPGO, SPGW, & SPGG, VISO, VISW, VISG, HO, HW, HG, SO, SW, SG, & SFTO, SFTW, WTO, WTW, WTG, TCRIT, PCRIT, TRED, & PRED, ZFAC, CONOIL, CONWAT, CONGAS)

The user subroutine supplies the parameters UNUM, TEMPIN, PRESIN, and Z (which is supplied to the user subroutine by PIPEPHASE). The remaining arguments are returned to the user subroutine by interface subroutine PVTCMP. Note that Z, X, Y, and W are vectors and must be dimensioned on a local dimension statement as follows:

DIMENSION Z(50), X(50), Y(50), W(50), AMW(50)

The significance of the various arguments are shown below in Table 4-61. Note that the data must be supplied and returned in the dimensional units as shown, regardless of the units selected on the DIMENSION statement for problem calculations.

Table 4-61: FLASH Routine Entries


UNUM A unique number between 1 and 99 to identify the call to PFTCMP

TEMPIN Temperature for calculations, R

PRESIN Pressure for calculations, psia

ENTH Total enthalpy of fluid, Btu/lb

QUAL Mass Fraction Vapor for the fluid

Z Fluid Composition, mol fraction, vector of 50

DUM1, DUM2 Dummy variables

X Oil Phase Composition, mol fraction, vector of 50

Y Vapor Phase Composition, mol fraction, vector of 50

W Water Phase Composition, mol fraction, vector of 50

HLNS No slip holdup

WLR Water/Liquid Ratio, volume basis

DENO Oil Density, Lb/ft3

DENW Water Density, Lb/ft3

DENG Gas Density, Lb/ft3

SPGO Oil Specific Gravity QQQ

SPGW Water Specific Gravity

SPGG Gas Specific Gravity (Dry Air = 1.0)


Note that the Z vector is supplied by PIPEPHASE in the calling vector for the user-defined DP correlation. Various temperatures and pressures are also supplied in the user-defined DP correlation argument list from PIPEPHASE.

Moody Friction Factor Interface

The user may retrieve Moody friction factors from PIPEPHASE through interface function FMOOD. Friction factors are retrieved with the following calling sequence:

where:

Examples

Examples of user-defined DP correlations are given in this category. The FORTRAN code is listed below. Note that these examples were developed for illustrative purposes and SimSci therefore makes no guarantee as to their accuracy or applicability.

VISO Oil Viscosity, cp

VISW Water Viscosity, cp

VISG Gas Viscosity, cp

HO Oil Enthalpy, BTU/Lb

HW Water Enthalpy, BTU/Lb

HG Gas Enthalpy, BTU/Lb

SO, SW, SQ Oil, Water, and Gas Entropies (Not currently available)

SFTO Oil Surface Tension, Dynes/cm

SFTW Water Surface Tension, Dynes/cm

WTO Oil Phase Molecular Weight

WTW Water Phase Molecular Weight

WTG Gas Phase Molecular Weight

TCRIT Pseudocritical temperature, °R

PCRIT Pseudocritical pressure, psia

TRED Reduced Temperature

PRED Reduced pressure

ZFAC Gas Compressibility Factor

CONOIL Oil Thermal Conductivity, BTU/hr-ft °F

CONWAT Water Thermal Conductivity, BTU/hr-ft °F

CONGAS Gas Thermal Conductivity, BTU/hr-ft ÉF

FF = FMOOD (REYN, ROUGH)

FF = Moody Friction Factor

REYN = Reynolds Number

ROUGH = Pipe Relative Roughness



Example 1 – Olimen’s Pressure Drop

The first example demonstrates the use of a user-added subroutine by calculating the two-phase pressure drop, using Olimen’s correlation with Eaton holdups and Moody friction factors. The two-thirds rule will be used for the pressure and temperature at which the properties will be computed.

SUBROUTINE HUSER1 1 (PIN, TIN, POUT, TOUT, PAVG, TAVG, ICOMP, IFLU, IDIR, IFLOW, 2 Z, DENO, DENG, DENW, DENL, VISO, VISW, VISL, 3 VISG, SFTO, SFTW, SFTL, QOPIP, QWPIP, QGPIP, 4 QTPIP, VELSL, VELSG, VELT, SPGG, SPGO, SPGW, 5 DIAM, AREA, RUFF, AINCL, EFF, DELX, NOACC, 6 DELP, DEN2, DPDLF, DPDLW, NREG, HL, CMW)CC- LOCAL DECLARATIONSC DIMENSION Z(50),CMW(50) DIMENSION X(50),Y(50),W(50)CC- CODE STARTS HERECC USE TWO-THIRDS RULE TO FIND TEMPERATURE AND PRESSUREC PUSE = PIN + (2. / 3.) * (PIN - POUT) TUSE = TIN + (2. / 3.) * (TIN - TOUT) + 459.67C

C WE NEED TO COMPUTE THE TOTAL MASS FLOW RATE UP FRONT BEFOREC THE CURRENT AVERAGE PROPERTIES ARE DESTROYED.C MASS RATE WILL BE IN LB/SECC RMASS = QOPIP * DENO + QWPIP * DENW + QGPIP * DENGCC NOW CALL PIPEPHASE FLASH ROUTINE TO GET PHYSICAL PROPERTIESC AT TUSE AND PUSEC UNUM = 99C CALL PVTCMP(0,UNUM,TUSE,PUSE,ENTH,QUAL,Z,DUM1,DUM2,AMW, 1 X,Y,W,HLNS,WLR,DENO,DENW,DENG,SPGO,SPGW, 2 SPGG,VISO,VISW,VISG,HO,HW,HG,SO,SW,SG, 3 SFTO,SFTW,WTO,WTW,WTG,TCRIT,PCRIT,TRED, 4 PRED,ZFAC,CONOIL,CONWAT,CONGAS)CC GAS HOLDUP AND NO-SLIP TWO-PHASE DENSITYC HGNS = 1. - HLNS DENL = WLR * DENW + (1. - WLR) * DENO DENNS = HLNS * DENL + HGNS * DENGCC VELOCITIESC QTPIP = RMASS / DENNS IF (DENG .NE. 0.0) QGPIP = QUAL * RMASS / DENG RMASSL = (1. - QUAL) * RMASS IF (DENL .NE. 0.0) QLPIP = RMASSL / DENL QWPIP = WLR * QLPIP QOPIP = (1. - WLR) * QLPIP VELSL = QLPIP / AREA VELSG = QGPIP / AREA VELT = QTPIP / AREACC LIQUID SURFACE TENSION AND NO-SLIP VISCOSITYC SFTL = WLR * SFTW + (1. - WLR) * SFTO VISL = WLR * VISW + (1. - WLR) * VISO VISNS = HLNS * VISL + HGNS * VISG


CC NO-SLIP REYNOLDS NUMBERC RNUM = 1488. * DENNS * VELT * DIAM / VISNSCC CALL PIPEPHASE ROUTINE TO GENERATE MOODY FRICTION FACTORSC FF = FMOOD(RNUM,RUFF)CC CALL PIPEPHASE ROUTINE TO COMPUTE THE EATON LIQUID HOLDUPC IF (HLNS .LT. 1.E-6 .OR. HLNS .GT. 0.99999) GO TO 1000C CALL EEXHL (PUSE, VELSL, VELSG, SFTL, DENL, 1 VISL, VISG, DIAM, HL)CC HOLDUP IS COMING BACK IN HL - CHECK BOUNDARIESC IF (HL .LT. HLNS) HL = HLNS IF (HL .GT. 1.0) HL = 1.0 GO TO 1010 1000 CONTINUE IF (HLNS .LT. 1.E-6) HL = 0.0 IF (HLNS .GT. 0.99999) HL = 1.0 1010 CONTINUECC TWO-PHASE DENSITY INCLUDING SLIPC DEN2 = HL * DENL + (1. - HL) * DENGCC MASS FLUXC BL = HL - HLNS GTP = RMASS / ((1. - BL) * AREA)CC EFFECTIVE DENSITY AND OLIMENS ADJUSTED DENSITYC DEFF = DIAM * SQRT(1. - BL) DOLI = (DENL * HLNS + DENG * HGNS) / (1. - BL)CC TOTAL FRICTION GRADIENTC DPDLF = -1. *(FF * GTP**2.) / (2. * DEFF* DOLI * 32.2 * 144.)CC ELEVATION GRADIENTC FOR DOWNHILL FLOW USE STATIC HEAD FROM GAS ONLY.C FOR UPHILL FLOW USE TOTAL TWO-PHASE STATIC HEAD.C IF (AINCL .LT. 0.0) GO TO 2000CC UPHILL OR VERTICAL FLOWC DPDLW = -1. * DEN2 * SIN(AINCL) / 144. GO TO 2010CC DOWNHILL FLOWC 2000 CONTINUEC DPDLW = -1. * DENG * SIN(AINCL) / 144.CC TOTAL GRADIENT - NO ACCELERATION TERM BEING COMPUTEDC 2010 CONTINUEC DPDLT = DPDLF + DPDLWCC TOTAL PRESSURE DROP ACROSS CALCULATION INCREMENTC DELP = DELX * DPDLTCC ALL DONE RETURN TO PROGRAM


C RETURN END

Example 2 – Fancher and Brown Pressure Drop

The second example calculates two-phase pressure drop using the correlation of Fancher and Brown. This routine is designed for use with non-compositional fluids.

SUBROUTINE HUSER2 1 (PIN, TIN, POUT, TOUT, PAVG, TAVG, ICOMP, IFLU, IDIR, IFLOW, 2 Z, DENO, DENG, DENW, DENL, VISO, VISW, VISL, 3 VISG, SFTO, SFTW, SFTL, QOPIP, QWPIP, QGPIP, 4 QTPIP, VELSL, VELSG, VELT, SPGG, SPGO, SPGW, 5 DIAM, AREA, RUFF, AINCL, EFF, DELX, NOACC, 6 DELP, DEN2, DPDLF, DPDLW, NREG, HL, CMW)CC PURPOSE: DEMONSTRATE THE USE OF THE USER-ADDED C SUBROUTINE BY CALCULATING THE TWO-PHASE PRESSURE C DROP USING THE CORRELATION OF FANCHER AND BROWN. CC AUTHOR(S): SIMSCICC COMPLETION DATE: 15 SEPTEMBER 2006CC- LOCAL DECLARATIONSC DIMENSION Z(50),CMW(50) DIMENSION X(50),Y(50),W(50) REAL MWGAS, MOLGAS, LOGFCC CODE STARTS HEREC COMPUTE THE NO-SLIP HOLDUP AND TWO-PHASE DENSITYC HLNS = (QOPIP + QWPIP) / QTPIP WLR = QWPIP / (QOPIP + QWPIP) DENL = WLR * DENW + (1. - WLR) * DENO DEN2 = HLNS * DENL + (1. - HLNS) * DENGC WRITE (1,*) ‘DENO,DENW,WLR,DENL,DEN2 = ‘C SINCE HOLDUP IS NOT CALCULATED BY FANCHER-BROWN, SET THE LIQDC HOLDUP TO THE NO-SLIP HOLDUPC HL = HLNSCC CALCULATE THE GAS-LIQUID RATIOC GLR = 0.0 IF (QGPIP .EQ. 0.0) GO TO 1000 MWGAS = SPGG * 28.972

WTGAS = QGPIP * DENG MOLGAS = WTGAS / MWGAS VOLGAS = MOLGAS * 379.5 QLPIP = QOPIP + QWPIP VOLLIQ = QLPIP / 5.615 GLR = VOLGAS / VOLLIQ 1000 CONTINUECC COMPUTE THE FANCHER-BROWN FRICTION FACTORC FRICTION FACTOR IS BASED ON THE GAS-LIQUID RATIOC RVD = DEN2 * VELT * DIAMC IF (GLR .GT. 1500) GO TO 1100C IF (RVD .GT. 15) GO TO 1050 LOGF = 11.96044 * (ALOG(RVD))**(-1.83104)


GO TO 2000 1050 CONTINUE LOGF = 0.09992 - 0.00106 * RVD GO TO 2000 1100 IF (GLR .GE. 3000) GO TO 1150 LOGF = 0.37028 - 0.01151 * RVD GO TO 2000 1150 CONTINUE LOGF = 0.215 - 0.01 * RVD 2000 CONTINUE FF = 10**LOGFCC COMPUTE THE TOTAL FRICTION GRADIENTC DPDLF = -1. * (FF * DEN2 * VELT**2.) / (2. * 32.2 * DIAM)CC COMPUTE THE ELEVATION GRADIENTC DPDLW = -1. * DEN2 * SIN(AINCL) / 144.CC COMPUTE THE TOTAL GRADIENT AND TOTAL PRESSURE DROPC NO ACCELERATION TERM IS CALCULATED HEREC DELP = DELX * (DPDLF + DPDLW)CC ALL DONE - RETURN TO C RETURN END


User-Defined Viscosity Correlation

The User-Defined Viscosity Correlation allows the user to define a user-added liquid viscosity of a black-oil model. This method is applicable only for black-oil fluid models.

Note: See p. 48 for keyword inputs.

Implementing the Correlation

The user-written method is selected in the same manner as the normal viscosity method such as API, Daqing, Twoelflin, etc.

User-defined viscosity correlations must be written in FORTRAN 77 and follow the naming and interface conventions described in this category. The subroutines are compiled and linked to the PIPEPHASE program.

The mechanics of program compilation and linking varies between computing platforms and are outside the scope of this manual. It is described in the installation manual for each platform.

Your SimSci representative can provide you with specific information regarding your particular system configuration. It is strongly recommended that user-written subroutines be thoroughly tested before incorporating into PIPEPHASE.

User Subroutine Specifications

The following argument list must be used for the user added viscosity correlation.

SUBROUTINE USRLIQVIS (QOPIP, QWPIP, DENO, DENW, SPGO, SPGW, PRES, TEMP, VISL, QOSTD, QWSTD)

The following input variables are modified through the process of defining a user-defined viscosity.

Input Variable Description Units

QOPIP In-Situ oil flow rate ft3/sec

QWPIP In-Situ water flow rate ft3/sec

DENO In-Situ oil Density lb/ft3

DENW IIn-Situ water density lb/ft3

SPGO Oil standard specific gravity

SPGW Water standard specific gravity

PRES Pressure psia

TEMP Temperature F

VISO Oil Viscosity cp

VISW Water Viscosity cp

QOSTD Oil standard flow rate ft3/sec


User-Added Viscosity Subroutine - Output Arguments

Common Blocks

The following internal common blocks must be included in the order presented.

The variable names /parameters used in USRVIS.CMN file are tabulated below

User is allowed up to 40 user-defined constants in designing a liquid viscosity correlation to be used in PIPEPHASE.

Note: New Method Name is stored in variable VISLMTH.

The USERVIS.CMN file contains the following lines. This file should never be changed.

PARAMETER (MX_CONS=40) CHARACTER*16 VISLABL, VISLMTHCOMMON /USRVIS1/VISLCON (MX_CONS), NVISCONS, VISLABL (MX_CONS), VISLMTH

Example Implementation

The following example shows how a user-added viscosity can be implemented in PIPEPHASE. The FORTRAN code is listed below. Note that this example was developed for illustrative propose and SimSci therefore makes no guarantee as to its applicability.

Example - Daqing Viscosity Correlation

SUBROUTINE USRLIQVIS 1 (QOPIP, QWPIP, DENO, DENW, SPGO, SPGW, VISO, VISW, 2 PRES, TEMP, QOSTD, QWSTD, VISL)C PURPOSE: DEMONSTRATE THE USE OF THE USER-ADDED SUBROUTINE IN C CALCULATING THE VISCOSITY USING DAQING CORRELATION.C AUTHOR (S): SIMSCI

QWSTD Water Standard flow rate ft3/sec

Output Variable Description Units

VISL Liquid viscosity cp

PARAM.CMN System- wide parameters

PRECIS.CMN Double precision statement

KCONS.CMN Dimensioning statement

USRVIS.CMN User defined viscosity

VISLCON (J) The Jth Constant for user defined Viscosity.

VISLABL (J) The Jth character label (16 characters) to describe VISLCON

VISLMTH Method label (16 characters)

NVISCONS Number of constants specified

Input Variable Description Units


C INPUT ARGUMENTC QOPIP - In-Situ oil flow rate, ft3/secC QWPIP - In-Situ water flow rate, ft3/secC DENO - In-Situ oil Density, lb/ft3C DENW - In-SituSitu water density, lb/ft3C SPGO - Oil standard specific gravityC SPGW - Water standard specific gravityC PRES - Pressure, psiaC TEMP - Temperature, FC VISO - Oil Viscosity, cpC VISW - Water Viscosity, cpC QOSTD - Oil standard flow rate, ft3/secC QWSTD - Water Standard flow rate, ft3/sec

C OUTPUT ARGUMENTSC VISL - Liquid viscosity, cpC MANDATED PIPEPHASE INCLUDE FILESINCLUDE 'PARAM.CMN'INCLUDE 'PRECIS.CMN'INCLUDE 'KCONS.CMN'INCLUDE 'USRVIS.CMN'

C SPECIFY DEFAULT EQUATION CONSTANTS CUT1 = 0.006 CUT2 = 0.74C C1 = 7.1546 C2 = 2.7885 C3 = 0.6C C4 = 7.2799 C5 = 2.8447 C6 = 0.6C C7 = 7.2244 C8 = 2.8506 C9 = 0.6C C10 = 1.0 C11 = 2.8461C C12 = 2.7183 C13 = 7.0C AA1 = 3.3811 CC1 = 1.562 CC2 = 2.7183 CC3 = -0.03702 CC4 = 35.0C CC5 = 2.7183 CC6 = 3.5 CC7 = 35.0 C AA2 = 3.3811 CC8 = 0.3892 CC9 = 2.7183 CC10= -0.02237 CC11= 50.0C CC12 = 2.7183 CC13 = 3.5 CC14 = 1.0073 CC15 = 35.0 IF (NVISCONS.GT.0) THENC CHECK FOR THE USER-DEFINED CONSTANT AND LABELS DECLAREDC DO 100 J = 1, NVISCONS IF (VISLABL (J). EQ.'CUT1') THEN CUT1 = VISLCON (J) ELSEIF (VISLABL (J). EQ.'CUT2') THEN CUT2 = VISLCON (J)


ELSEIF (VISLABL (J). EQ.'C1') THEN C1 = VISLCON (J) ELSEIF (VISLABL (J). EQ.'C2') THEN C2 = VISLCON (J) ELSEIF (VISLABL (J). EQ.'C3') THEN C3 = VISLCON (J) ELSEIF (VISLABL (J). EQ.'C4') THEN C4 = VISLCON (J) ELSEIF (VISLABL (J). EQ.'C5') THEN C5 = VISLCON(J) ELSEIF(VISLABL(J).EQ.'C6') THEN C6 = VISLCON(J) ELSEIF(VISLABL(J).EQ.'C7') THEN C7 = VISLCON(J) ELSEIF(VISLABL(J).EQ.'C8') THEN C8 = VISLCON(J) ELSEIF(VISLABL(J).EQ.'C9') THEN C9 = VISLCON(J) ELSEIF(VISLABL(J).EQ.'C10') THEN C10 = VISLCON(J) ELSEIF(VISLABL(J).EQ.'C11') THEN C11 = VISLCON(J) ELSEIF(VISLABL(J).EQ.'C12') THEN C12 = VISLCON(J) ELSEIF(VISLABL(J).EQ.'C13') THEN C13 = VISLCON(J) ELSEIF(VISLABL(J).EQ.'AA1') THEN AA1 = VISLCON(J) ELSEIF(VISLABL(J).EQ.'CC1') THEN CC1 = VISLCON(J) ELSEIF(VISLABL(J).EQ.'CC2') THEN CC2 = VISLCON(J) ELSEIF(VISLABL(J).EQ.'CC3') THEN CC3 = VISLCON(J) ELSEIF(VISLABL(J).EQ.'CC4') THEN CC4 = VISLCON(J) ELSEIF(VISLABL(J).EQ.'CC5') THEN CC5 = VISLCON(J) ELSEIF(VISLABL(J).EQ.'CC6') THEN CC6 = VISLCON(J) ELSEIF(VISLABL(J).EQ.'CC7') THEN CC7 = VISLCON(J) ELSEIF(VISLABL(J).EQ.'CC8') THEN CC8 = VISLCON(J) ELSEIF(VISLABL(J).EQ.'AA2') THEN AA2 = VISLCON(J) ELSEIF(VISLABL(J).EQ.'CC9') THEN CC9 = VISLCON(J) ELSEIF(VISLABL(J).EQ.'CC10') THEN CC10 = VISLCON(J) ELSEIF(VISLABL(J).EQ.'CC11') THEN CC11 = VISLCON(J) ELSEIF(VISLABL(J).EQ.'CC12') THEN CC12 = VISLCON(J) ELSEIF(VISLABL(J).EQ.'CC13') THEN CC13 = VISLCON(J) ELSEIF(VISLABL(J).EQ.'CC14') THEN CC14 = VISLCON(J) ELSEIF(VISLABL(J).EQ.'CC15') THEN CC15 = VISLCON(J) ENDIF 100 CONTINUE ENDIFC WTWAT = DENW * QWPIP WTOIL = DENO * QOPIP WATCUT = WTWAT / (WTWAT + WTOIL)CC When weight water cut is less than 0.006 use pure oil viscosityC correlation IF (WATCUT.LT. CUT1) THEN


C Absolute temperature Kelvin conversion TAVGC = (TEMP - 32.0)/1.8 +273.15 SPLL = DENO/62.4 VIS1 = 10.0**(10**(C1 - C2*LOG10 (TAVGC))) - C3C VIS2 = 10.0**(10**(C4 - C5*LOG10 (TAVGC))) - C6C VIS3 = 10.0**(10**(C7 - C8*LOG10 (TAVGC))) - C9C VISL = (VIS1 + VIS2 + VIS3)/3.0 VISL = SPLL * VISLC ELSEIF (WATCUT.GT. CUT2) THEN PHIO = QOPIP / (QOPIP + QWPIP)C PHI = PHIO * (C10 + C11)C VISL = VISW * C12 ** (C13 * PHI) ELSECC Temperature to centigrade conversionC TAVGC = (TEMP - 32.0)/1.8 IF (TAVGC.LE. 50.0) THEN AA1 = 3.3811C CC = CC1 * CC2 ** (CC3 * (CC4 + TAVGC))C VISL = CC5 ** (AA1 + CC6 * WATCUT + CC * (CC7 - TAVGC)) ELSE AA2 = 3.3811C CC = CC8 * CC9 ** (CC10 * (CC11 + TAVGC))C VISL = CC12 ** (AA2 + CC13 * WATCUT - CC14 1 + CC * (CC15 - TAVGC)) ENDIF ENDIFC ----------------------------------------------------------------C ---------------- END OF ROUTINE USRLIQVIS----------------------C ---------------------------------------------------------------- RETURN END


Inflow Performance Relationship (IPR)

The inflow performance represents the production rate from the petroleum reservoir as a function of the drawdown, which is the difference in pressure between the reservoir and the flowing well.

User-Defined IPR

The inflow performance relationship (IPR) for a completion zone within a well is a relationship defining the production rate from the formation as a function of the drawdown. The drawdown is a measure of the driving force represented by the pressure differential between the undisturbed reservoir and the flowing well (usually at the sand-face).

The IPR Model is defined as a type of PIPEPHASE device (other examples: PIPE, PUMP, COMPLETION). Structurally, an IPR device should be configured downstream of a pressure-boundary source. It will be the first (or upstream-most) element in a link representing the connection between the well source and the surface gathering system (the exception will be an injection sink where it will be the last device before the downstream sink). Like any other device, an IPR device is a subprogram where the inlet flow conditions of pressure, temperature and enthalpy, are processed as a function of the flow rate through the device to calculate the outlet pressure.

The output from the IPR device model are the downstream or outlet conditions of pressure, temperature and enthalpy. For most IPR devices, where temperature and enthalpy variations can be ignored, the only relevant output from the IPR model is the outlet pressure. In certain instances, the value of one or more of the internal process variables are of significance to the end-user (e.g., breakthrough time from a coning model). These variables are the secondary output from an IPR device model.

Built-in Variable List

A comprehensive set of “built-in IPR variables” have been made available for use as labels in a user-defined IPR. This set, created for the internally-supported IPR models, represents most of the commonly-used variables in defining IPRs. Note that the set of available real variables are further subdivided by defining a separate “indexed” category of variables, to be used for defining tabular data related to time-stepping and production planning. Tables 4-62 through 4-65 show the lists of available variables.

Keyword Input

The keywords required for input to any user-defined model have been described elsewhere. These keywords are required for two purposes:

• To add to the list of in-built variables as needed for a specific IPR; and


• To define the IPR characteristics for each of the completion zones associated with an IPR device.

Subprogram Structure

A model number is selected from the available slots (numbers 1-20 are reserved for internal development). The model number will be the basis for the corresponding subroutine name: IPRnn, where nn represents the model number in I2.2 format (e.g., SUBROUTINE IPR06, or SUBROUTINE IPR99). The calling arguments to the standard IPRnn subroutine will be:

SUBROUTINE IPRnn (P, T, H, WT, QOSTD, QGSTD, QWSTD, IPRERR)

The following input variables are modified through the process of the IPR device from inlet (upstream) to outlet (downstream) conditions:

Note that for isenthalpic, isothermal IPR models, the pressure is the only variable that changes.

The input variables are defined as:

Note: The mass flowrate is applicable for composition and steam models.

The corresponding output variable:

Common Blocks

The following internal common blocks must must be included:

P pressure, psia

T temperature, deg F

H enthalpy, Btu/lb

WT mass flowrate, lb/sec

QOSTD oil flowrate at standard conditions, ft3/sec

QGSTD gas flowrate at standard conditions, ft3/sec

QWSTD water flowrate at standard conditions, ft3/sec

IPRERR - error code (0 - no error)

PARAMS.CMN System-wide parameters

PRECIS.CMN Double precision statement

KCONS.CMN Dimensioning statement

PRMIPR.CMN IPR-related parameters

CUNIT.CMN Unit conversions


The following common block will be needed for IPR models that use the pseudo-pressure function utility:

The following local character declarations are needed to support the internal utility modules and data handling facilities:

Data Extraction

The input data specific to an IPR defined through the keywords RVAL, IVAL and ARRAY will be extracted through the following utility modules:

for extracting real values; and

for extracting integer values (note that an extract utility will not be provided for ARRAY data in the initial release).

The variables in the calling arguments are:

Units Conversion Utility

The units conversion utility is described in , p. 4-220.

IPRCON.CMN In-situ density values (lb/ft3) for IPR calculation; these variables may be used to develop user-added IPRs:

CONGDN - gas densityCONODN - oil densityCONWDN - water density

MFPCMN.CMN - common block for pseudo-pressure utility

CHARACTER LABEL *(MXCHAR), IFOUND*1

CHARACTER*(MXCHAR) RLABEL(3), ILABEL(1)

SUBROUTINE RXTRCT (LABEL, NCHAR, IFOUND, RVAL)

SUBROUTINE IXTRCT (LABEL, NCHAR, IFOUND, RVAL)

LABEL - variable label defined in the keyword input

NCHAR - number of unique identifying characters in the label

IFOUND - character flag (Y/N) indicating whether label was found

RVAL/IVAL - specific real/integer value


Calculation Utilities

The function of utility modules is to provide the developer of the user-added IPR with a set of common tools that can reduce the development effort, provide consistency across models, and eliminate the duplication of code. For the initial release, the calculation utility modules provided have been restricted to a set of subroutines representing coning calculations in horizontal wells. In particular, these are:

• The Giger coning model for determining the critical rate, and

• The Papatzakos method for calculating the time for breakthrough.

In addition this model will also determine the optimal well placement for dual (water table and gas cap) drive reservoirs.

The Giger et al coning model calculates the critical oil production rate at which coning occurs:

The output variable is:

The input variables are:

The Papatzakos et al. coning model calculates the breakthrough time for coning in a horizontal well. For a dual cone model, when both gas cap and bottom water drive exist, it also determines the optimal well placement in terms of the distance to the oil-water contact in a vertical plane.

SUBROUTINE GIGER (KCAP, RKH, VISO, FVF, DENO, DENW, DENG, WSPA, THICK, RLENG, QCRIT)

QCRIT - critical oil production rate, STB/D

KCAP - drive mechanism (1-bottom water, 2-gas cap, 3-dual)

RKH - horizontal permeability, mD

VISO - oil viscosity, cp

FVF - oil formation volume factor, reservoir volume per unit stock tank volume

DENO - oil density, lb/ft3

DENW - water density, lb/ft3

DENG - gas density, lb/ft3

WSPA - spacing between horizontal wells (or drainage length), ft

THICK - thickness of oil producing zone, ft

RLENG - length of horizontal well, ft

SUBROUTINE PAPAT (KCAP, RKH, RKZ, VISO, FVF, DENO, DENW, DENG, RLENG, THICK, PHI, QO, TBT, OPT)


The output variables are:

The input variables are:

Secondary Output Utility

An output utility module has been developed to report (both output report and Results Access) internal variables of interest (e.g., results from coning model):

All of the calling arguments are input variables:

Example Implementation

The following is an example for a user-added IPR in slot 21 (slot numbers 1-20 reserved for internal models). This is a simple PI model for an oil producing formation.

SUBROUTINE IPR21 (P,T,H,WT,QOSTD,QGSTD,QWSTD,IPRERR)C This subprogram determines the flowing well pressure in an oil (or water) wellC from the reservoir pressure and the production rates. For injection wells,itC computes the pressure in the reservoir from the incoming flowing well pressure.

TBT - time to breakthrough, days

OPT - optimal placement (distance to oil/water contact in a vertical plane), ft

KCAP - drive mechanism (1-bottom water, 2-gas cap, 3-both)

RKH - horizontal permeability, mD

RKZ - vertical permeability, mD

VISO - oil viscosity, cp

FVF - oil formation volume factor, reservoir volume per unit stock tank volume

DENO - oil density, lb/ft3

DENW - water density, lb/ft3

DENG - gas density, lb/ft3

RLENG - length of horizontal well, ft

THICK - thickness of oil producing zone, ft

PHI - reservoir porosity

QO - oil production rate, STB/D

SUBROUTINE RINSRT (RVAL, NREAL, IVAL, NINT, RLABEL, ILABEL, MREAL, MINT)

RVAL - array of real values

NREAL - number of variables in RVAL array

IVAL - array of integer values

NINT - number of integers in IVAL array

RLABEL - 20-character label array corresponding to RVAL

ILABEL - 20-character label array corresponding to IVAL

MREAL - maximum number of variables in RVAL array (20)

MINT - maximum number of variables in IVAL array (5)


C Note: this algorithm is not valid for gas-basis deliverability calculations.C Input Arguments:C P pressure, psiaC QOSTD oil flowrate, std.ft3/secC QWSTD water flowrate, std.ft3/secC Output Arguments:C P pressure, psiaC IPER error flag (0 - no error)C Unused:C WT mass flowrate, lb/secC QGSTD gas flowrate, std.ft3/sec

C Mandated PIPEPHASE include Files INCLUDE ‘PARAM.CMN’ INCLUDE ‘PRECIS.CMN’ INCLUDE ‘KCONS.CMN’ INCLUDE ‘PRMIPR.CMN’ INCLUDE ‘CUNIT.CMN’ INCLUDE ‘MFPCMN.CMN’C Mandated Declaration CHARACTER LABEL *(MXCHAR), IFOUND*1 CHARACTER*(MXCHAR) RLABEL(3), ILABEL(1)C Declarations for Output Utility PARAMETER (MREAL = 20) PARAMETER (MINT = 5) DIMENSION RXVAL(MREAL), IXVAL(MINT)C Initialize IPRERR = 0 LABEL(1:4) = ‘ ‘C Extract Deliverability Basis LABEL(1:5) = ‘BASIS’ CALL IXTRCT (LABEL,4,IFOUND,IVAL) IF (IFOUND. EQ. ‘Y’) THEN IBASIS = IVAL ELSE IPRERR = 1 GO TO 999 ENDIFC Extract Productivity Index LABEL(1:2) = ‘PI’ CALL RXTRCT (LABEL,2,IFOUND,RVAL) IF (IFOUND.EQ.’Y’) THEN PI = RVAL ELSE IPRERR = 2 GO TO 999 ENDIFC Extract Traverse Direction Flag LABEL(1:2) = ‘FLOW’C Default traverse: pressure drop ISIGN = - 1 CALL IXTRCT (LABEL,2,IFOUND,IVAL) IF ((IFOUND .EQ. ‘Y’) .AND. (IVAL .EQ. 2)) ISIGN = + 1C Note: this is just an illustration of the use of this flag (the only C practical examples of pressure gain across a device would be a pump C or a compressor model).C Convert flowrate from internal units to user (keyword) units ININDX = 2 INTCLS = 3 IOTNDX = IUTVEC (1, INTCLS, 1) Q1 = TOBU (Q, INTCLS, ININDX) Q = FROMBU (Q1, INTCLS, IOTNDX) C Deliverability Basis C Basis = liquid (oil & water) IF (IBASIS .EQ. 2) THEN Q = QOSTD + QWSTDC Basis = oil ELSEIF (IBASIS .EQ. 3) THEN Q = QOSTD ELSEIF (IBASIS .EQ. 4) THENC Basis = water Q = QWSTD


C Unsupported basis ELSE IPRERR = 3 GO TO 999 ENDIFC Calculate Drawdown DD = PI * QC Secondary Output RXVAL(1) = DD RLABEL(1) = Pressure Drawdown = CALL RINSRT (RXVAL, 1, IXVAL, 0, RLABEL, ILABEL, MREAL, MINT)C Convert drawdown from user units to internal () units INTCLS = 10 ININDX = IUTVEC (1, INTCLS, 1) IOTNDX = 1 DD = TOBU (DD, INTCLS, ININDX)C Calculate Downstream Pressure from Drawdown P = P + ISIGN * DD999 CONTINUE RETURN END

Variables and Arrays for User-Defined IPR Models

Real Variables

Table 4-62: Available Real Variables

(Usage: RVAL=LABEL1,X1/LABEL2,X2....)

CLAMINAR laminar flow coefficient in LIT formulation

COEF coefficient of gas deliverability equation

CPSS constant in pseudo steady-state equation

CTURBULENT turbulent flow coefficient in LIT formulation (default=0.0)

CUMVOL cumulative volume produced (default=0.0)

ECHG elevation change

EXP exponent of gas deliverability equation (default=0.5)

FVF liquid formation volume factor

ID diameter of tubular at sand-face through which significant pressure drop occurs (used when NSEG1)

KX permeability in x-direction

KY permeability in y-direction

KZ permeability in z-direction (vertical permeability)

LENGTH length of horizontal well, or producing zone thickness for vertical wells

MPCONS constant in pseudo-pressure integral (default=2.0)

PDEPTH depth of measurement point (default=sandface)

PMIN minimum pressure limit (also reference) for pseudo-pressure calc.

PMAX maximum pressure limit for pseudo-pressure calculation (default=reservoir pressure)

PI productivity index

PITURB coefficient of turbulent flow term in PI equation (default=0.0)

PRES reservoir pressure

QMAX maximum flowrate or absolute open flow potential (AOFP) in Vogels equation

RESA length (coarse) of reservoir in x-direction (perpendicular to well)


Indexed Real Variables

Table 4-63: Available Indexed Real Variables (used for TABULAR)

RESB width (coarse length) of reservoir in y-direction (parallel to well)

RW wellbore radius

SKIN dimensionless reservoir infinitesimal skin (default=0.0)

SPI specific productivity index, PI per unit length (used when NSEG1)

THICKNESS average formation thickness

VISL liquid phase viscosity

VOGCONS constant in Vogels equation (default=0.2)

VOGEXP exponent in Vogels equation

XCORD x-coordinate of the horizontal well

Y1CORD y1-coordinate of the horizontal well

Y2CORD y2-coordinate of the horizontal well

ZCORD z-coordinate of the horizontal well

(Usage: RVAL=LABEL“ij”,X1/LABEL”ij”,X2....)

PRESi reservoir pressure at i-th” cumulative production volume

TQCUMi “i-th” cumulative (default fluid) production volume (for i=1,..,5); based on fluid model:liquid - liquid volumegas - gas volumeblackoil - oil and water volumecondensate - gas volumecompositional - masssteam - mass

TQGCUMi “i-th” cumulative gas production volume (for i=1,..,5)

TQLCUMi “i-th” cumulative liquid production volume

TQOCUMi “i-th” cumulative oil production volume

TQWCUMi “i-th” cumulative water production volume

PWFij flowing well pressure at “i-th” cumulative production (or reservoir pressure), for the j-th” point on the IPR curve (for j=1,...6)

QFij “j-th” flowrate on the IPR curve for the “i-th” cumulative production (or reservoir pressure)

(Usage: RVAL=LABEL1,X1/LABEL2,X2....)


Integer Variables

Table 4-64: Available Integer Variables

Note: For user defined IPR, each user has the freedom to define his or her own labels and interpret the data in any way. The RXTRCT and IXTRCT utilities extract the real and integer data by label.

(Usage: IVAL=LABEL1,I1/LABEL2,I2....)

BASIS deliverability basis:1- gas2- liquid3- oil4- water5- mass

DRAWDOWN basis for drawdown calculation:0- conventional (default): difference of squares of pressures for gas; difference in

actual pressures for liquid basis

1- difference in pseudo-pressure function m(p) for gasbasis, with the integration constant equal to 2

2- difference in pseudo-pressure function m(p) for gas basis with integration constant calculated from

Tsc = standard temperature (519.67 °R)Psc = standard pressure (14.7 psia)Tres = reservoir temperature

3- difference in m(p) for gas basis, with user-specified const

IMODEL model used for curve fitting (default = linear interpolation)1- Productivity index (straight line)2- Vogel3- Fetkovich4- LIT

FLOW traverse direction:1- forward (default)2- reverse

NPSEG number of segments for pseudo-pressure calculations (default=50)

NSEG number of equal IPR segments; when NSEG 1, PIPEPHASE internally creates sub-surface sources. This feature is useful in modeling horizontal wells or excessively thick vertical pay zones

Cons ttanTsc

PscTres------------------=


Arrays

Table 4-65: Available Arrays(Usage: ARRAY=LABEL1,X1,X2,X3.../LABEL2,Y1,Y2,Y3...)

AQCUM cumulative reservoir fluid production; based on fluid model:

liquid - liquid volumegas - gas volumeblackoil - oil and water volumecondensate - gas volumecompositional - masssteam - mass

AQGCUM cumulative reservoir gas production

AQLCUM cumulative reservoir liquid production

AQOCUM cumulative reservoir oil production

AQWCUM cumulative reservoir water production

PPRES reservoir pressure (as a function of cumulative production)

DECLINERATE pressure-compressibility (p/z) decline rate for gas reservoirs


Chapter 5 Results

Chapter Contents

About This Chapter . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2Report Options . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3Description of Reports . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3

Input Reprint . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3Intermediate Printout . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4Solution Output. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4

Input Reprint Examples . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8Thermodynamic Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8Component Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8General Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9PVT Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10Network Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11Source Data. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11Structure Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12Network Connectivity. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13Case Study . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13Sizing Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14Nodal Analysis (Sensitivity). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15Lift Gas Data. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15PVTGEN Results . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 16

Intermediate PRINTOUT Example . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 17Network Directory . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 17Inflow Performance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 18

Solution Output Examples . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19Flash Report . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19Separator Report . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 20Link Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 20Node Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 21Device Summary. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 21Structure Data Summary. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 22


Velocity Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 22Results Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 23Link Device Detail Report . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 23Pressure and Temperature Report . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 24Pressure and Temperature Plots . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 25Phase Envelope Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 26Phase Envelope Plot . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 27Holdup and Velocity Report. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 28Pressure Gradient Detail Report . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 29Taitel-Dukler-Barnea Flow Regime Map. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 30Link Property Detail Report . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 30Viscosity and Density Results . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 31Friction and Surface Tension Results . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 31Heat Transfer Calculations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 32Slug Report . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 33Case Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 34Nodal Analysis (Sensitivity). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 35Sphering Report . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 37Results Access System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 38

About This Chapter

This chapter contains information about the reports produced by PIPEPHASE. It describes which reports are available and gives examples of many types.

The chapter first gives a full list of the reports available, along with brief descriptions. The list is in the order in which the reports will appear in your output. If you want to know what reports you must produce in order to get any specific information, this is where to look. This chapter also tells you which reports are always produced, which are produced by default, and which are produced only by specific request. The options to request or suppress each report are also described.

The chapter then goes on to give examples of the reports. The examples are presented in the same order as the list of reports. For clarity and brevity’s sake, the output shown is not the complete output from a specific run. To illustrate the different features, selected parts of the output are taken from examples given in the PIPEPHASE Application Briefs.

5-2 Results

Report Options

The PIPEPHASE ASCII output is designed to provide concise information within 80 columns. The main PRINT statement in the General Data Category of input (see the PRINT statement in Chapter 4, Input Reference) controls the overall level of printout. A number of printout options are available to enable you to select the amount of information that you require. For example, if additional information for only some of the links is required, you need only set the PRINT option on the LINK statements for the ones you want. If the PRINT option is entered on any link, detail reports will not be produced for links which do not also have the PRINT option.

If stream property tables are being generated, tables and plots of the properties against temperature and pressure can be produced by using the PRINT and PLOT options on the GENERATE statement.

The output is normally produced in the units of measurement you defined globally as input units. Instead of this output, or in addition to it, you can request an output in a different set of units using the OUTDIMENSION statement in the General Data Category of the input.

Description of Reports

The output from a simulation is in three main sections that correspond to the three phases of the PIPEPHASE simulation run. These are the input check and input data reprint, intermediate solution history and output, and the final results output. PIPEPHASE will only continue from one section to the next if no errors are detected. If errors are found, either in the user’s input data or during the solution procedure itself, self-explanatory messages will be printed and the simulation will either terminate or, in the case of a solution procedure error, PIPEPHASE will try to resolve the problem and continue with the simulation.

Input Reprint

A reprint of your keyword input data file will always be created showing any syntax errors you have made. If there are no syntax errors, PIPEPHASE then cross-checks the data for logic and consistency. By default, it also prints out the full set of input data which shows all the default values used, as well as the user-supplied data. All, or part, of this full input data reprint can be suppressed, if desired.

The full input data reprint shows the data for all the data sections in the simulation. All the possible categories of input are as follows:


Table 5-1: Input Data Categories

A single simulation run cannot include all these data sections. For options, see PRINT, p. 4-28.

Intermediate Printout

During solution of a network, PIPEPHASE iterates until it converges to within the error tolerance you set or that is set by default. A summary of any errors or warnings encountered during that iteration will be produced at the end of each iteration. The ITER option on the PRINT statement can be used to request additional printout which shows flowrates and pressures at each iteration of the solution path. This can be particularly useful if you have inadvertently given conflicting specifications in the problem setup and the program has failed to resolve the inconsistencies.

If well test data have been specified, the inflow performance coefficient is calculated before the solution calculations and the report appears in the intermediate output.

Solution Output

The solution output is made up of a number of sections as shown below. These sections are listed in the order they appear in the output report, although not all simulation modes will produce all sections (see Chapter 3, Using PIPEPHASE).

Component Data General DataThermodynamic Data PVT DataAssay Data Source DataStructure Data Network ConnectivityCase Study Sizing DataTime Stepping Data Optimization DataPVTGEN Results Sensitivity Analysis Data

Table 5-2: Solution Output To specify... See...Flash Report A flash report is produced by default for each node

in a compositional run unless property tables are being used. This report contains the temperature, pressure, composition, flowrate, and properties for each phase present at each node. The flash report can be suppressed by the FLASH=NONE option on the PRINT statement.

P. 4-28 PRINT

Separator Report A separator report is produced for each separator in a compositional run unless property tables are being used. This report contains the temperature, pressure, composition, flowrate, and properties for each separator product.

P. 4-28 PRINT

5-4 Results

Link Summary The link summary is produced by default for all PIPEPHASE simulations and shows the flowrates, pressure, temperature, and holdups for each link in a tabular format. The flowrates displayed are the volumetric rates at actual flowing conditions for each phase. This report can be suppressed by the SUMM=NEW option on the PRINT statement.

P. 4-28 PRINT

Node Summary The node summary is produced by default and shows the flowrates, pressure, and temperature at each node in a tabular format. The flowrate is shown for each phase, but the flow basis depends on the fluid type. For a single-phase liquid or gas, standard volumetric rates are shown. If the non-compositional fluid is steam, weight flowrates and quality are printed. For a compositional fluid, weight flowrates and gravity are also given. This report can be suppressed by the SUMM=NEW option on the PRINT statement.

P. 4-28 PRINT

Device Summary The device summary is produced by default and summarizes each device (pipe, fitting, or item of process equipment) in the order in which they were defined in the link. The table shows the correlation used, inside diameter, length, elevation change, liquid holdup and the outlet temperature, pressure and liquid fraction. The device summary can be suppressed by the DEVICE=NONE or SUMM=NEW options on the PRINT statement.

P. 4-28 PRINT

Structure Data Summary

The structure data summary is produced by default and contains information for link devices including length, elevation change and K-factor. This report can be suppressed by the SUMM=OLD option on the PRINT statement.

P. 4-28 PRINT

Velocity Summary The velocity summary is produced by default and contains link fluid velocity-related information such as inlet and outlet velocities, critical velocity (see , Critical Flow - A Qualitative Description), pressure gradient and the pressure drop per device. This report can be suppressed by the SUMM=OLD option on the PRINT statement.

P. 4-28 PRINT

Results Summary The results summary is produced by default and contains flow, pressure, temperature and quality information for device inlet and outlet points. This report can be suppressed by the SUMM=OLD option on the PRINT statement.

P. 4-28 PRINT

Table 5-2: Solution Output (cont.)To specify... See...


Link Device Detail Report

The DEVICE=PART or DEVICE=FULL option on the PRINT statement generates a link device detail report for every link in the simulation. The PRINT option on the LINK statements can be used to restrict the report to specific links. The report for each link is in several sections:

P. 4-28 PRINTP. 4-89 LINK

Pressure and Temperature Report - For pipes and fittings, this shows the dimensions, pressure, temperature, heat transfer coefficient, and ambient temperature. For items of process equipment, the calculated parameters, such as pump power or valve resistance coefficient, are shown.

Pressure and Temperature Plots - If the PLOT=FULL option is specified on the PRINT statement, the pressure and temperature profiles along the link are plotted.

Phase Envelope - For compositional fluids, a phase envelope is produced when the PLOT=FULL option is specified. A phase envelope plot and tabular data are both shown.

Holdup and Velocity Detail Report - The liquid holdup, liquid, gas and mixed phase fluid velocities, flow regime, and sonic velocity are shown for each calculation segment in the link.

Pressure Gradient Detail Report - This report is only produced if the DEVICE=FULL option is invoked on the PRINT statement. It shows the pressure gradient and pressure drop in each calculation segment and identifies the frictional and elevation contributions of this value.

Taitel-Dukler Flow Regime Map - This is produced for two-phase flow in links by specifying the MAP=TAITEL option on the PRINT statement along with DEVICE=PART or DEVICE=FULL.


5-6 Results

Link PropertyDetail Report

The PROPERTY=PART or PROPERTY=FULL option on the PRINT statement generates a link property detail report for every link in the simulation. The PRINT option on the LINK statements can be used to restrict the report to specific links. The report for each link is in several sections:.

P. 4-28 PRINTP. 4-89 LINK

Viscosity and Density Results - This report shows the viscosity and density at actual flowing conditions for each phase at each calculation segment.

Friction and Surface Tension Results - In addition to the friction factor and surface tension, this report shows the Reynolds number and the other properties from which the friction factor is calculated.

Heat Transfer Calculations - This report is produced only if the PROPERTY=FULL option is specified on the PRINT statement. The report shows fluid thermal conductivity and the thermal resistances for each calculation segment. For compositional or steam simulations, the phase enthalpies are also shown. Hydrate formation is flagged for compositional runs

Slug Report The SLUG option is used to create a Statistical Slug Model report. DEVICE=PART or DEVICE=FULL must be specified on the PRINT statement and the report is only produced for single link calculations with two-phase flow at the outlet.

P. 4-28PRINT

Case Summary This report is produced for all simulations which use the case study feature. The report summarizes the node pressures, temperatures and flowrates for each case study to allow easy comparisons of the cases.

Sensitivity Analysis

When the sensitivity analysis feature is used, none of the standard link, node, or device reports are produced. Instead, a special sensitivity analysis output is generated. It compares the node pressures, temperatures, and flowrates for each of the specified inflow and outflow parameters. Results are presented in tabular and graphical form.

P. 5-35Nodal Analysis (Sensitivity)

Sphering Report This report is produced for all sphering calculation runs. It shows the pressure, temperature, and flowrate in the zones in front of, and behind, the sphere as it proceeds along the pipeline. It also shows the slug delivery time and rate and the time required for the pipeline to re-establish steady state.

P. 5-35Nodal Analysis (Sensitivity)



Input Reprint Examples

The input data reprint can be lengthy for large networks and can be partially or fully suppressed by entering INPUT=PART or INPUT=NONE on the PRINT statement in the General Data Category of input. It is generally best to use the default (INPUT=FULL) when first running a simulation and only reduce the amount of reprint when the data are known to be correct. Even with INPUT=NONE, the keyword data file is always printed to the output.

Thermodynamic Data

Component Data

The following data section appears at the front of the data reprint when INPUT=FULL is entered on the PRINT statement. Component properties for the thermodynamic set are reprinted first.

DATA FOR SET 'SET01' GRAYSON STREED PURE COMPONENT DATA COMP CRITICAL CRITICAL ACENTRIC MOLAR SOLUBILITY TEMPERATURE PRESSURE FACTOR VOLUME PARAMETER DEG F PSIG BBL/LB-MOL ---- ---------- ---------- ---------- ---------- ---------- 1 90.14 693.65 0.1064 0.1940 6.0500 2 206.01 601.65 0.1538 0.2397 6.4000 3 274.96 514.36 0.1825 0.3010 6.7300 4 305.60 536.40 0.1953 0.2893 6.7300 5 369.03 475.71 0.2104 0.3349 7.0200 6 385.70 473.94 0.2387 0.3312 7.0200 7 423.16 547.27 0.2348 0.2944 7.6741 8 454.42 518.46 0.2548 0.3159 7.7260 9 483.27 493.03 0.2750 0.3367 7.7673 10 511.30 469.34 0.2961 0.3577 7.8024

This is followed by the thermodynamic method for each unit operation (usually the same).

THERMODYNAMIC SETS USED FOR EACH UNIT OPERATION DEFAULT METHOD IS SET01 THERMODYNAMIC SET UNIT OPERATIONS ----------------- --------------- SET01

A list of the methods used for each thermodynamic property is then shown.

THERMODYNAMIC METHODS USED FOR EACH SET THERMODYNAMIC SET SET01 (DEFAULT) PROPERTY METHOD -------- ------ KVALUE(VLE) GRAYSON-STREED KVALUE(LLE) UNSPECIFIED KVALUE(SLE) UNSPECIFIED LIQUID ENTHALPY LEE-KESLER VAPOR ENTHALPY LEE-KESLER LIQUID DENSITY API VAPOR DENSITY LEE-KESLER LIQUID ENTROPY CURL-PITZER VAPOR ENTROPY CURL-PITZER LIQUID VISCOSITY PETROLEUM VAPOR VISCOSITY PETROLEUM LIQUID CONDUCTIVITY PETROLEUM VAPOR CONDUCTIVITY PETROLEUM SURFACE TENSION PETROLEUM LIQUID DIFFUSIVITY UNSPECIFIEDNote: The above is an extract from Example 3 of Applib files.

5-8 Results

General Data

In this example, the first components are from the library and the rest are from an assay.

COMPONENT NBP CRIT. TEMP. CRIT. PRES. CRIT. VOLM. F F PSIG BBL/LB-MOL--------------------- ----------- ----------- ----------- ----------- 1 C2 -127.534 90.140 693.648 0.4222 2 C3 -43.726 206.006 601.652 0.5792 3 IC4 10.886 274.964 514.358 0.7503 . . . . . . . . . . 7 NBP 111 111.803 423.164 547.267 0.8123 8 NBP 138 138.274 454.420 518.464 0.8810 9 NBP 163 163.294 483.268 493.027 0.9482 10 NBP 188 188.139 511.305 469.336 1.0173

COMPONENT ACEN. FACT. HEAT FORM. G FORM. BTU/LB-MOL BTU/LB-MOL --------------------- ----------- ----------- ----------- 1 C2 0.09860 -36120.21 -13810.45 2 C3 0.15290 -44650.04 -10139.64 3 IC4 0.17720 -57870.16 -9121.45 4 NC4 0.20130 -54072.23 -7169.22 . . . . . . . . 7 NBP 111 0.23478 -13716.71 MISSING 8 NBP 138 0.25480 -30070.22 MISSING 9 NBP 163 0.27497 -35014.72 MISSING 10 NBP 188 0.29608 -40097.76 MISSINGNote: The above report is an extract from Example 3 of Applib files.

By default, fixed properties are listed for all components in the simulation. This includes library components, defined petroleum components and assay derived pseudo-components.

COMPONENT COMP. TYPE PHASE MOL. WEIGHT API--------------------- ----------- ----------- ----------- ----------- 1 C2 LIBRARY VAP/LIQ 30.070 265.526 2 C3 LIBRARY VAP/LIQ 44.097 147.208 3 IC4 LIBRARY VAP/LIQ 58.124 119.788 . . . . . . . . . . 7 NBP 111 ASSAY CUT VAP/LIQ 72.781 68.931 8 NBP 138 ASSAY CUT VAP/LIQ 79.282 65.928 9 NBP 163 ASSAY CUT VAP/LIQ 85.654 63.249 10 NBP 188 ASSAY CUT VAP/LIQ 92.207 60.727

This includes all the dimensional units, global default values, flow codes and print options.

CALCULATION OPTIONS RUN TYPE........ NETWORK FLUID TYPE...... LIQUID HEAT BALANCE WILL BE TURNED OFF DIMENSIONAL UNITS - ENGLISH TEMPERATURE..... DEG F PRESSURE........ PSIG MOLAR RATE...... MOLE/HR WEIGHT RATE..... LB/HR LIQUID RATE..... GAL/MIN VAPOR RATE...... MM FT3/HR COARSE LENGTH... FT FINE LENGTH..... IN DENSITY/GRAVITY. DEG API VISCOSITY....... CP DUTY............ MM BTU/HR POWER........... HP VELOCITY........ FT/SEC

ADDITIONAL OUTPUT UNITS - SI DEFAULTS FLOW EFFICIENCY............ 100.00 PERCENT HAZEN-WILLIAMS COEFF....... 150.00 ROUGHNESS.................. 0.00180 IN AMBIENT TEMPERATURE........ 80.00 DEG F TEMPERATURE GRADIENT....... 1.00 DEG F/100 FT TUBING U-FACTOR............ 1.000 BTU/HR-FT2-F ANNULUS U-FACTOR........... 1.000 BTU/HR-FT2-F INSIDE FILM COEFFICIENT.... 0.000 BTU/HR-FT2-F OUTSIDE FILM COEFFICIENT... 0.000 BTU/HR-FT2-F RADIANT COEFFICIENT........ 0.000 BTU/HR-FT2-F INSIDE DIAMETER - PIPE..... 4.026 IN INSIDE DIAMETER - TUBING... 4.026 IN INSIDE DIAMETER - ANNULUS.. 6.065 IN THICKNESS - PIPE........... 0.200 IN


PVT Data

CONDUCTIVITY - PIPE........ 29.000 BTU/HR-FT-F THICKNESS - INSULATION - LAYER 1.................. 0.000 IN LAYER 2.................. 0.000 IN LAYER 3.................. 0.000 IN LAYER 4.................. 0.000 IN LAYER 5.................. 0.000 IN

CONDUCTIVITY - INSULATION - LAYER 1.................. 0.015 BTU/HR-FT-F LAYER 2.................. 0.015 BTU/HR-FT-F LAYER 3.................. 0.015 BTU/HR-FT-F LAYER 4.................. 0.015 BTU/HR-FT-F LAYER 5.................. 0.015 BTU/HR-FT-F

FLOW CODES PIPE FLOW CODE IS HAZEN-WILLIAMS REYNOLDS NUMBER(LAMINAR)..... 3000.0000 TUBING FLOW CODE IS MOODY ANNULUS FLOW CODE IS MOODY

BASE CONDITIONS STANDARD TEMPERATURE....... 60.00 DEG F STANDARD PRESSURE.......... 0.000 PSIG

PRINT OPTIONS INPUT........... GENERAL ASSAY COMPONENT PVT FLOW TABLE METHOD SOURCE STRUCTURE CASE STUDY GAS LIFT W ANALYSIS CONNECT......... FULL PVTGEN.......... NONE SUMMARY......... BOTH DEVICE.......... PART MAP............. TAITEL-DUKLER-BARNEA PROPERTY........ FULL SEGMENTATION OPTIONS LENGTH CHANGE - HORIZONTAL....... 2000.0 FT VERTICAL......... 500.0 FT MAXIMUM NUMBER OF SEGMENTS....... 50 AUTOSEGMENT OPTION IS ................ ON TARGET SEGMENT PRESSURE CHANGE........ 2.0000E+01 PSIG TARGET SEGMENT TEMPERATURE CHANGE..... 5.0000E+00 DEG F SEGMENT PRESSURE ERROR ............... 2.0000E-01 PSIG SEGMENT ENTHALPY ERROR ............... 5.0000E-02 BTU/LB NUMBER OF INTERNAL SEGMENT ITERATIONS. 25

Note: The above report is an extract from Example 1 of Applib files.

The gravity, viscosity, and specific heat have been entered for a non-compositional run. The default options are also shown.

PVT DATA SUMMARY 1 CORRELATION DATA SETS 0 ERRORS 0 WARNINGS DEFAULT PVT METHODS OPTIONS Z FACTOR METHOD.......... STANDING LIQUID VISCOSITY METHOD.. FOR OIL VAZQUEZ (TUFFP) FOR WATER BEAL CORRELATION SET DATA CORRELATION SET NUMBER 1 GRAVITY OF LIQUID......... 46.0620 DEG API VISCOSITY OF LIQUID 32.00 DEG F ........ 0.3950 CP 122.00 DEG F ........ 0.2460 CP SPECIFIC HEAT OF OIL...... 0.5250 BTU/LB-FNote: The above report is an extract from Example 1 of Applib files.

5-10 Results

Network Data

Source Data

In this example, property tables have been requested for a compositional run

PVT DATA SUMMARY 1 CORRELATION DATA SETS 0 ERRORS 0 WARNINGS CORRELATION SET DATA CORRELATION SET NUMBER 1 PVT TABLE GENERATION DATA SET NUMBER 1 TABLE TYPE.............. 1 NO. PRESSURE POINTS..... 4 INITIAL PRESSURE........ 10.0000 PSIG PRESSURE DIFFERENCE..... 40.0000 PSIG NO. TEMPERATURE POINTS.. 16 INITIAL TEMPERATURE..... 0.0000 DEG F TEMPERATURE DIFFERENCE.. 30.0000 DEG F PRESSURE TEMPERATURE NO PSIG DEG F -- -------- ----------- 1 10.000 0.00 2 50.000 30.00 3 90.000 60.00 4 130.000 90.00 5 120.00 6 150.00 7 180.00 8 210.00 9 240.00 10 270.00 11 300.00 12 330.00 13 360.00 14 390.00 15 420.00 16 450.00 TABLES OF THE FOLLOWING PROPERTIES WILL BE PRINTED LIQ DENSNote: The above report is an extract from Example 3 of Applib files.

The Solution Methods/ Tolerances are shown for network calculations only.

SOLUTION METHODS/TOLERANCES NETWORK SOLUTION METHOD IS PBAL MAXIMUM ITERATIONS..................... 40 MAXIMUM NUMBER OF INTERVAL HALVINGS.... 3 CLOSED LOOP PREVENTION OPTION IS ...... ON ABSOLUTE PRESSURE TOLERANCE............ 0.250 PSIG0 RATE PERTURBATION...................... 0.010000 METHOD OF INITIAL SOLUTION ESTIMATION.. FLOW = 2 ZERO FLOW IN CHECK VALVES.............. OFF CHOKE CRITICAL FLOW MODEL (FORTUNATI) . EXPONENTIAL NEW ACCELERATION OPTION IS............. OFF

Note: The above report is an extract from Example 11 of Applib files.

Compositional source - the composition of defined components as well as rate, pressure and temperature are shown.

SOURCE FEED PHASE IS MIXED THIS SOURCE IS ON PVT SET NUMBER............ 1 RATE...................... 1500000.0000 LB/HR PRESSURE.................. 114.0001 PSIG TEMPERATURE............... 60.00 DEG FNote: The above report is an extract from Example 3 of Applib files.


Structure Data

Blackoil source - characterized by gas/oil ratio and water cut. A rate estimate was entered for this source. The Vogel Index is only shown when a value has been entered.

SOURCE RES THIS SOURCE IS ON PVT SET NUMBER............ 1 ESTIMATED OIL RATE........ 50.0001 M3/HR WATER CUT................. 5.00 PERCENT GAS/OIL RATIO............. 320.0008 M3/M3 PRESSURE.................. 400.0000 BAR TEMPERATURE............... 110.00 DEG CNote: The above report is an extract from Example 2 of Applib files.

Condensate source - condensate/gas ratio and water /gas ratio characterize the fluid. The pressure was estimated for this source.

SOURCE 1 THIS SOURCE IS ON RATE...................... 85.0000 MM FT3/DAY WATER/GAS RATIO........... 0.0000 BBL/MM FT3 CONDENSATE/GAS RATIO...... 0.0000 BBL/MM FT3 ESTIMATED PRESSURE........ 263.0001 PSIG TEMPERATURE............... 85.00 DEG FNote: The above report is an extract from Example 9 of Applib files.

Non-compositional liquid or gas - no phase change data may be entered.

SOURCE S1 THIS SOURCE IS ON ESTIMATED RATE............ 499.9988 MM FT3/DAY PRESSURE.................. 375.0001 PSIG TEMPERATURE............... 97.00 DEG F

Note - The above report is an extract from Example 4 of Applib files.Steam source - either temperature or quality must be supplied.

SOURCE STM THIS SOURCE IS ON PVT SET NUMBER............ 1 RATE...................... 33000.0000 LB/HR QUALITY................... 97.00 PERCENT VAPOR PRESSURE.................. 170.0001 PSIG

Note - The above report is an extract from Example 10 of Applib files.

All information, including defaulted parameters, is shown for each flow device and equipment item along each link in the simulation. Estimated parameters at each junction and sink are also listed.

LINK 4

LINK IS FROM "J2 " TO "PROD "

DEVICE SA025, Z025, IS A PIPE FLOW CODE IS BEGGS-BRILL (MOODY) INSIDE DIAMETER.............. 10.0000 IN LENGTH....................... 5.0 FT ELEVATION CHANGE............. 0.0 FT FLOW EFFICIENCY.............. 100.00 PERCENT HEAT LOSS COEFFICIENT........ 1.00000 BTU/HR-FT2-F ROUGHNESS.................... 0.00180 IN AMBIENT TEMPERATURE.......... 80.00 DEG F

DEVICE WA026, Z026, IS AN EXPANSION FLOW CODE IS CHISHOLM UPSTREAM INSIDE DIAMETER..... 10.00 IN DOWNSTREAM INSIDE DIAMETER... 12.00 IN EXPANSION ANGLE ANGLE...... 135.00 DEG LAMDA (CHISHOLM PARAMETER)... 1.00000 C2 (CHISHOLM PARAMETER)...... CALCULATED NUMBER OF DEVICES............ 1

5-12 Results

Network Connectivity

Case Study

DEVICE SA027, Z027, IS A PIPE FLOW CODE IS BEGGS-BRILL (MOODY) INSIDE DIAMETER.............. 12.0000 IN LENGTH....................... 40.0 FT ELEVATION CHANGE............. 0.0 FT FLOW EFFICIENCY.............. 100.00 PERCENT HEAT LOSS COEFFICIENT........ 1.00000 BTU/HR-FT2-F ROUGHNESS.................... 0.00180 IN AMBIENT TEMPERATURE.......... 80.00 DEG F

DEVICE SA028, E4 , IS A DPDT THIS IS A SURFACE DEVICE PRESSURE DROP CURVE FLOWRATE, DELTA P DELTA T LB/HR PSIG DEG F ----------- ----------- ----------- 1 0.500E+06 -10.00 50.00 2 0.150E+07 -5.00 40.00

DEVICE SA029, Z029, IS A PIPE FLOW CODE IS BEGGS-BRILL (MOODY) INSIDE DIAMETER.............. 12.0000 IN LENGTH....................... 40.0 FT ELEVATION CHANGE............. 0.0 FT FLOW EFFICIENCY.............. 100.00 PERCENT HEAT LOSS COEFFICIENT........ 1.00000 BTU/HR-FT2-F ROUGHNESS.................... 0.00180 IN AMBIENT TEMPERATURE.......... 80.00 DEG FNote - The above report is an extract from Example 3 of Applib files.

The connectivity shows the sources, junctions, and sinks. It does not show any of the flow devices within the links.

NODE CONNECTIONS ---- CONNECTIONS ---- NODE NODE NAME NODE TYPE TO NODE VIA LINK ---- --------- --------- --------- --------- FEED FEED SOURCE J1 1 PROD PROD SINK J2 4 J1 J1 JUNCTION FEED 1 J2 2 J2 3 J2 J2 JUNCTION J1 2 J1 3 PROD 4

LINK CONNECTIONS LINK LINK NAME FROM NODE TO NODE ---- --------- --------- ---------- 1 1 FEED J1 2 2 J1 J2 3 3 J1 J2 4 4 J2 PROD

+----------------------------------------+ | | | +----+ +----+ +----+ +----+ | | |FEED|----|J1..|----|J2..|----|PROD| | | |SRCE| |....| |....| |SINK| | | +----+ +----+ +----+ +----+ | | | | | | | | | | +---------+ | | | | | | | +----------------------------------------+Note: The above report is an extract from Example 3 of Applib files.

All the case studies are summarized on this report.

CASE NUMBER 1 ----------------- NEW OLD DEVICE NAME VARIABLE UNITS VALUE VALUE ========================================================================= PIPE GFROM ROUGHNESS IN 0.00100 PIPE GNETWORK ROUGHNESS IN 0.00200


Sizing Data






The pipe sizes which may be used during the sizing calculations are listed. If no sizes were entered by the user, the standard Schedule 40 sizes shown here are used.

LINE DATA ========= PIPE DIAMETER IN ========= 1.049 1.610 2.067 2.469 3.068 3.548 4.026 5.074 6.065 7.981 10.020 11.938 13.124 15.000 16.876 18.814 22.626Note - The above report is an extract from Example 10 of Applib files.

All the devices on this list will be sized.

DEVICES TO BE SIZED =================== NAME DEVICE TYPE ==== =========== Z001 PIPE Z002 PIPE Z003 PIPE Z004 PIPE Z005 PIPE Z006 PIPE Z007 PIPENote - The above report is an extract from Example 10 of Applib files.

5-14 Results

Nodal Analysis (Sensitivity)

Lift Gas Data

This example shows both an inflow and an outflow section. The inflow section has 5 source pressures and the outflow has 4 different pipe diameters.

SOLUTION NODE IS AT NODE C008 (INLET OF DEVICE IF IT IS A DEVICE NAME) FLOW RATES, BBL/DAY 500.00 1500.00 2500.00 4000.00 6000.02 7000.01 8000.01 9000.00 10000.00 11999.99 INFLOW SECTION SENSITIVITY TO SOURCE PARAMETERS DESCRIPTION ----------- CASE 1 DEPLETED CASE 2 3YEARSPRES CASE 3 LOWPRES CASE 4 CURRENTPRES CASE 5 HIGHPRESS CASE 1 CASE 2 CASE 3 CASE 4 CASE 5 SOURCE ,S001 PRESSURE PSIG 4000.00410 4500.00410 5000.00410 5500.00410 6000.00410 CASE 1 CASE 2 CASE 3 CASE 4 CASE 5 OUTFLOW SECTION SENSITIVITY TO STRUCTURE PARAMETERS OUTFLOW SECTION NODAL ANALYSIS VARIABLES ARE CALCULATED IN ONE TO ONE COMBINATION DESCRIPTION ----------- CASE 1 3INCH CASE 2 35INCH CASE 3 4INCH CASE 4 5INCH CASE 5 6INCH CASE 1 CASE 2 CASE 3 CASE 4 CASE 5 PIPE ,P009 ID IN 3.00000 3.50000 4.00000 5.00000 6.00000 PIPE ,P010 ID IN 3.00000 3.50000 4.00000 5.00000 6.00000 PIPE ,P011 ID IN 3.00000 3.50000 4.00000 5.00000 6.00000 CASE 1 CASE 2 CASE 3 CASE 4 CASE 5Note - The above report is an extract from Example 12 of Applib files.

This report shows the input data for the selected gaslift option.

WELL CAPACITY CALCULATION LIFT GAS INPUT PRESSURE... 950.0001 PSIG LIFT GAS INPUT TEMPERATURE 100.00 DEG F GAS ALLOWED TO DISSOLVE... 100.00 PERCENT GASLIFT VALVE DEPTH....... 5900.0 FT RATE, CASE MM FT3/DAY ---- ---------- 1 0.0010 2 0.2000 3 0.4000 4 0.6000 5 0.8000 6 1.0000 7 2.0000 8 3.0000 9 4.0000



PVTGEN Results

The stream is flashed and properties are calculated, at each of the specified temperature/pressure pairs. This example has 5 pressures and 16 temperatures and so 80 flashes are required.

SET NUMBER 1 PRESSURE TEMPERATURE COMPOSITION NO PSIG PSIA DEG F DEG F MOLE FRACT. __ _____ _____ _____ _____ ______ 1 0.0000 14.6959 0.00 0.00 0.003116 2 10.0000 24.6959 30.00 30.00 0.006055 3 50.0000 64.6959 60.00 60.00 0.007642 4 90.0000 104.6959 90.00 90.00 0.018506 5 130.0000 144.6959 120.00 120.00 0.011347 6 150.00 150.00 0.027595 7 180.00 180.00 0.022891 8 210.00 210.00 0.027509 9 240.00 240.00 0.037115 10 270.00 270.00 0.050918 11 300.00 300.00 0.049701 12 330.00 330.00 0.040284 13 360.00 360.00 0.035045 14 390.00 390.00 0.031831 15 420.00 420.00 0.029831 16 450.00 450.00 0.028681

80 POINTS FLASHED

STREAM MOLECULAR WEIGHT... 228.96CRITICAL TEMPERATURE...... 789.97 DEG FCRITICAL PRESSURE......... 310.16 PSIG


Tables and plots may be requested for any of the fluid properties. The Vapor Viscosity tables are shown here.

LIQUID DENSITY DEG API TEMPERATURE DEG F PRESSURE ------------------------------------------------------------- PSIG 0.00 30.00 60.00 90.00 120.00 150.00 180.00 -------- ------- ------- ------- ------- ------- ------- ------- 0.00 26.735 28.859 30.999 33.172 35.394 37.684 39.912 10.00 26.721 28.843 30.982 33.153 35.374 37.662 40.038 50.00 26.666 28.779 30.911 33.076 35.291 37.573 39.942 90.00 26.611 28.716 30.841 33.000 35.209 37.485 39.847 130.00 26.557 28.655 30.773 32.926 35.129 37.399 39.754 TEMPERATURE DEG F PRESSURE ------------------------------------------------------------- PSIG 210.00 240.00 270.00 300.00 330.00 360.00 390.00 -------- ------- ------- ------- ------- ------- ------- ------- 0.00 41.603 42.901 43.919 44.803 45.668 46.572 47.537 10.00 42.524 44.677 46.205 47.384 48.373 49.307 50.267 50.00 42.419 45.030 47.800 50.760 53.944 56.214 57.708 90.00 42.316 44.916 47.673 50.616 53.778 57.196 60.913 130.00 42.214 44.804 47.547 50.472 53.612 57.002 60.683 TEMPERATURE DEG F PRESSURE -------------------- PSIG 420.00 450.00 -------- ------- ------- 0.00 48.565 49.657 10.00 51.287 52.377 50.00 58.977 60.179 90.00 64.248 65.998 130.00 64.703 69.117


5-16 Results

Intermediate PRINTOUT Example

For network calculations, the intermediate printout details the path that the program took to get to the final solution.

Network Directory

If the ITER option is not specified on the PRINT statement, then only the maximum and RMS (root mean square) average pressure imbalances are printed.Spur links are printed after the network has converged.

PAGE CONTENTS ———— ———————————————————————————————————————————— 1 INTERMEDIATE PRINTOUT

CONVERGENCE TOLERANCE 0.5 PSI PRESSURE IMBALANCE AT SELECTED NODES (RMS VALUE USED FOR STEP-SIZE SELECTION)

ITERATION NUMBER 0.0

LINK FROM TO FLOW RATE PRESSURE IN PRESSURE OUT IMBALANCE NAME NODE NODE M LB/HR PSIA PSIA PSIA———— ———— ———— ——————————— ——————————— ——————————— ——————————— Q-I Q I 33.000 179.70 179.53R-E R E 40.000 179.70 176.64W-A W A 70.000 184.70 184.25A-B A B 62.000 184.25 183.29M-B M B 30.000 184.70 183.56 0.271B-D B D 2.000 183.29 183.27E-D E D 28.000 176.64 176.12 -7.150D-F1 D F 27.073 183.27 179.17D-F2 D F 2.927 183.27 182.90 3.724F-G F G 20.439 179.17 179.01F-H F H 9.561 179.17 178.76G-H G H 5.439 179.01 178.99 0.223I-H I H 33.000 179.53 177.94 -0.823G-N G N 15.000 179.01 177.77 3.073 MAX PRESSURE IMBALANCE = 7.150 PSI AT NODE D RMS AVERAGE PRESSURE IMBALANCE = 3.541 PSI

First iteration: ITERATION NUMBER 1.0

LINK FROM TO FLOW RATE PRESSURE IN PRESSURE OUT IMBALANCE NAME NODE NODE M LB/HR PSIA PSIA PSIA———— ———— ———— ——————————— ——————————— ——————————— ——————————— Q-I Q I 33.000 177.71 177.53R-E R E 40.000 181.81 178.79W-A W A 70.000 179.75 179.28A-B A B 62.000 179.28 178.29M-B M B 30.000 179.46 178.29 -0.001B-D B D 2.000 178.29 178.28E-D E D 28.000 178.79 178.28 -0.003D-F1 D F 22.954 178.28 175.28D-F2 D F 7.046 178.28 175.94 0.662F-G F G 22.481 175.28 175.07F-H F H 7.519 175.28 175.02G-H G H 7.481 175.07 175.03 0.013I-H I H 33.000 177.53 175.92 0.904G-N G N 15.000 175.07 173.81 -0.894 MAX PRESSURE IMBALANCE = 0.904 PSI AT NODE H RMS AVERAGE PRESSURE IMBALANCE = 0.585 PSI


Inflow Performance

Second iteration: ITERATION NUMBER 2.0

LINK FROM TO FLOW RATE PRESSURE IN PRESSURE OUT IMBALANCE NAME NODE NODE M LB/HR PSIA PSIA PSIA———— ———— ———— ——————————— ——————————— ——————————— ——————————— Q-I Q I 33.000 177.70 177.53R-E R E 40.000 182.49 179.48W-A W A 70.000 180.43 179.97A-B A B 62.000 179.97 178.98M-B M B 30.000 180.14 178.98 0.000B-D B D 2.000 178.98 178.97E-D E D 28.000 179.48 178.97 0.000D-F1 D F 22.270 178.97 176.16D-F2 D F 7.730 178.97 176.14 -0.016F-G F G 22.617 176.16 175.95F-H F H 7.383 176.16 175.91G-H G H 7.617 175.95 175.91 0.000I-H I H 33.000 177.53 175.92 0.007G-N G N 15.000 175.95 174.69 -0.007

MAX PRESSURE IMBALANCE = 0.016 PSI AT NODE F RMS AVERAGE PRESSURE IMBALANCE = 0.007 PSI

These are spur links: ******************************************** PBAL SOLUTION CONVERGED AFTER 2 ITERATIONS ******************************************** LINK FROM TO FLOW RATE PRESSURE IN PRESSURE OUT NAME NODE NODE M LB/HR PSIA PSIA ———— ———— ———— ——————————— ——————————— ———————————— H-S H S 18.000 175.91 174.66 H-P H P 30.000 175.91 168.55 E-L E L 12.000 179.48 178.93 B-K B K 90.000 178.98 176.11 A-J A J 8.000 179.97 179.90

The IPR coefficient is calculated from well test data and used in all subsequent calculations.

INFLOW PERFORMANCE CALCULATION RESULTS -------------------------------------- WELL NAME PROD IPR TYPE PI TEST DATA TEST 1 FLOW RATE 421.1(BPD) GOR 500.(CFBBL) OUTLET PRESSURE 142.0(PSIG) OUTLET TEMPERATURE 109.0(F) CALCULATED RESULTS FLOWING BOTTOMHOLE PRESS 1739.1(PSIG) HEAT TRANSFER COEFFICIENT 1.843(BTU/HRFT2F) IPR COEFFICIENTS (CALCULATED)


5-18 Results

Solution Output Examples

The solution output for PIPEPHASE can be very brief or extremely lengthy, depending on the problem and the level of output selected. In general, it is best to start with the default output and only request additional information where required. In large network runs, put the PRINT keyword on only those links where specific information is desired.

Flash Report

By default, flash reports are produced for every node in a compositional run unless property tables are being used. The reports can be suppressed by specifying FLASH=NONE on the PRINT statement.

NODE SINK AT 6.7 DEG C AND 87.0 BAR --------------------MOLE FRACTION------------------- ----HYDROCARBON---- COMBINED TOTAL COMPONENT VAPOR LIQUID1 VAP+LIQ1 LIQUID2 STREAM ----------------- -------- -------- -------- -------- -------- N2 0.004003 0.000442 0.004000 0.000000 0.004000 CO2 0.004121 0.003518 0.004120 0.000000 0.004120 C1 0.957304 0.384112 0.956800 0.000000 0.956800 C2 0.033951 0.055872 0.033970 0.000000 0.033970 C3 0.000289 0.001288 0.000290 0.000000 0.000290 NC4 0.000099 0.001172 0.000100 0.000000 0.000100 NC5 0.000019 0.000588 0.000020 0.000000 0.000020 NC6 0.000009 0.000697 0.000010 0.000000 0.000010 C7PLUS 0.000204 0.552312 0.000690 0.000000 0.000690 TOTAL RATE (INLET TO NODE IF JUNCTION) KG/HR 8.5815E5 4117.44 8.6226E5 0.00 8.6226E5 KG-M/HR 5.1313E4 45.197 5.1358E4 0.000 5.1358E4 WT FRAC LIQ 0.004775 0.004775 PHASE PROPERTIES ---------------- MASS FRACTION 0.995225 0.004775 1.000000 0.000000 1.000000 VOLUME FRAC 0.999487 0.000513 1.000000 0.000000 1.000000 DENSITY LB/FT3 4.76 44.41 0.00 ACTUAL SPGR 0.577239 0.712141 0.000000 VISCOSITY CP 0.0132 0.2573 0.0000 ENTHALPY KCAL/KG 26.474 2.178 0.000 26.358 SURF TENS NEWTON/M 0.016 0.000 MOLECULAR WT 16.7238 91.1003 16.7892 0.0000 16.7892



Separator Report

Link Summary

A report is produced for every separator present in a compositional run unless property tables are being used.

SEPARATOR S016 AT 20.6 DEG C AND 103.5 BAR ----------- MOLE FRACTION ------------ FLUID FLUID COMPONENT FEED REMAINING REMOVED --------- ---------- ---------- ---------- CO2 0.009900 0.009900 0.000000 C1 0.200000 0.200000 0.000000 C2 0.210000 0.210000 0.000000 C3 0.520000 0.520000 0.000000 IC4 0.021100 0.021100 0.000000 NC4 0.014000 0.014000 0.000000 NC5 0.007500 0.007500 0.000000 NC6 0.007500 0.007500 0.000000 NC7 0.005000 0.005000 0.000000 NC10 0.005000 0.005000 0.000000 PHASE LIQUID LIQUID VAPOR TOTAL, 10**3 KG/HR 111.82 111.82 0.00 WT PCT TOTAL LIQUID 100.00 100.00 0.00 ENTHALPY KCALKG 13.84 13.84 0.00 MOLECULAR WEIGHT 37.33 37.33 0.00 VAPOR PHASE ----------- GAS MM M3/HR 0.0000 0.0000 0.0000 DENSITY KG/M3 0.00 0.00 0.00 VISCOSITY CP 0.000 0.000 0.000 ENTHALPY KCALKG 0.00 0.00 0.00 MOLECULAR WEIGHT 0.00 0.00 0.00 LIQUID PHASE ------------ LIQUID M3/HR 259.62 259.62 0.00 DENSITY KG/M3 430.70 430.70 0.00 VISCOSITY CP 0.066 0.066 0.000 ENTHALPY KCALKG 13.84 13.84 0.00 MOLECULAR WEIGHT 37.33 37.33 0.00


This report shows the rate, pressure, and temperature at each end of every link. By default, the report appears on every PIPEPHASE output. You may suppress it by specifying the SUMM=NEW option on the PRINT statement.

BASE CASE LINK SUMMARY RATE, PRESSURE AND TEMPERATURE SUMMARY -------------------------------------- FROM(F) AND TO(T) ----ACTUAL FLOW RATES***-- PRESS: ---HOLDUP**--- LINK NODE GAS OIL WATER PRESS: DROP TEMP: GAS LIQ (MMCFD) (BPH) (BPH) (PSIG) (PSIG) (F) (MM (ABBL) SCF) ---- ------- -------- -------- -------- -------- ------- ----- ------- ------- 1 FEED(F) 0.0000 4913.45 0.00 114.0* 60.0 J1 (T) 0.0000 5001.67 0.00 106.3 7.7 100.2 0.0000 8.0 SPHERE GENERATED VOLUME (BASED ON HL) = 0.0 SPHERE GENERATED VOLUME (BASED ON (HL-HLNS))= 0.0 2 J1 (F) 0.0000 1942.03 0.00 106.3 100.2 J2 (T) 0.0000 1985.71 0.00 92.6 13.6 149.4 0.0000 9.7 SPHERE GENERATED VOLUME (BASED ON HL) = 0.0 SPHERE GENERATED VOLUME (BASED ON (HL-HLNS))= 0.0 3 J1 (F) 0.0000 3059.65 0.00 106.3 100.2 J2 (T) 0.0000 3112.53 0.00 92.6 13.6 138.1 0.0000 9.7 SPHERE GENERATED VOLUME (BASED ON HL) = 0.0 SPHERE GENERATED VOLUME (BASED ON (HL-HLNS))= 0.0 4 J2 (F) 0.0000 5098.21 0.00 92.6 142.5 PROD(T) 0.0000 5193.55 0.00 87.4 5.3 182.4 0.0000 11.7 SPHERE GENERATED VOLUME (BASED ON HL) = 0.0 SPHERE GENERATED VOLUME (BASED ON (HL-HLNS))= 0.0 * - INDICATES KNOWN PRESSURE ** GAS VOLUME REPORTED AT USER STANDARD CONDITIONS *** RATE REPORTED AT ACTUAL TEMPERATURE AND PRESSURE CONDITIONS


5-20 Results

Node Summary

Device Summary

This report shows the rate, pressure, and temperature at each source, sink and junction. By default, the report on every PIPEPHASE output. You may suppress it by specifying the SUMM=NEW option on the PRINT statement.

BASE CASE NODE SUMMARY NODE PRES. -------GAS---- ------OIL------ ----WATER------ TOTAL TEMP RATE GRAV RATE GRAV RATE GRAV RATE (PSIG) (LBHR) (LBHR) (LBHR) (LBHR) (F) ---- ------- -------- ------ -------- ------ -------- ----- -------- ------- FEED 114.0 * 0. 0.000 1500000. 0.870 0. 0.000 1500000. *60.0000 0.0000(MMCFD) 4919.48(BPH) 0.00(BPH) J1 106.3 0. 0.000 0. 0.870 0. 0.000 0. *1.002E2 0.0000(MMCFD) 0.00(BPH) 0.00(BPH) J2 92.6 0. 0.000 0. 0.870 0. 0.000 0. *1.424E2 0.0000(MMCFD) 0.00(BPH) 0.00(BPH) PROD 87.4 0. 0.000 -1.500E6 0.870 0. 0.000 -1.500E6 1.824E2 0.0000(MMCFD) -4919.48(BPH) 0.00(BPH) * INDICATES KNOWN PRESSURE OR FLOW ** FLOW RATES REPORTED AT USER STANDARD CONDITIONS


This report gives summary information about each flow device, fitting, and equipment item in the simulation. It appears by default on every output. You can suppress it by specifying DEVICE=NONE or SUMM=NEW on the PRINT statement.

This example shows a well with an IPR device, tubing, and a surface pipeline.

DEVICE SUMMARY C O ------- OUTLET ------ AVG.LINK DEVI DEVI R INSIDE MEAS ELEV INSITU LIQNAME NAME TYPE R DIAM LENGTH CHNG PRESS: TEMP: GLR HOLDUP (IN) (FT) (FT) (PSIG) (F) (CFBBL)---- ---- ---- ---- -------- --------- ------- ------- ------ ------- ------A-B **JUNCTION** RATE= 33632.8 (BPD) 287.0 214.4 GLR= 617. A 287.0 214.4 Z016 PIPE BB 19.000 70000.0 -100.0 242.5 145.4 35. 0.31 B **JUNCTION** PRES= 242.5 (PSIG) TEMP= 159.0 (F) A1-A ***SOURCE*** RATE= 6827.4 (BPD) 2000.0 220.0 GLR= 617. A1 2000.0 220.0 IPR1 IPR 0.000 0.0 0.0 1513.4 220.0 0. 0.00 Z002 TBNG HB 3.476 5000.0 5000.0 418.0 216.1 19. 0.45 Z003 PIPE BB 3.476 1000.0 0.0 287.0 214.5 30. 0.30 A **JUNCTION** PRES= 287.0 (PSIG) TEMP= 214.4 (F) -A ***SOURCE*** RATE= 6598.0 (BPD) 2000.0 220.0 GLR= 617. A2 2000.0 220.0 IPR2 IPR 0.000 0.0 0.0 1520.1 220.0 0. 0.00 Z005 TBNG HB 3.476 5500.0 5200.0 388.4 215.4 22. 0.45 Z006 PIPE BB 3.476 800.0 -5.0 287.0 214.1 31. 0.29 A **JUNCTION** PRES= 287.0 (PSIG) TEMP= 214.4 (F) A3-A ***SOURCE*** RATE= 6676.0 (BPD) 2000.0 220.0 GLR= 617. A3 2000.0 220.0 IPR3 IPR 0.000 0.0 0.0 1497.8 220.0 0. 0.00 Z008 TBNG HB 3.476 5000.0 4950.0 424.7 216.0 19. 0.45 Z009 PIPE BB 3.476 1100.0 5.0 287.0 214.3 30. 0.30 A **JUNCTION** PRES= 287.0 (PSIG) TEMP= 214.4 (F) A4-A ***SOURCE*** RATE= 6595.4 (BPD) 2000.0 220.0 GLR= 617. A4 2000.0 220.0 IPR4 IPR 0.000 0.0 0.0 1548.8 220.0 0. 0.00 Z011 TBNG HB 3.476 5500.0 5300.0 394.4 215.3 21. 0.45 Z012 PIPE BB 3.476 850.0 0.0 287.0 213.9 31. 0.29 A **JUNCTION** PRES= 287.0 (PSIG) TEMP= 214.4 (F)



Structure Data Summary

Velocity Summary

This report shows the major parameters for each item in the simulation. By default, the report appears on every PIPEPHASE output. You may suppress it by specifying the SUMM=OLD option on the PRINT statement.

BASE CASE STRUCTURE DATA SUMMARY DEVICE DEVICE INLET DIA OUTLET DIA ELEVATION KMUL OR LINK NAME TYPE (NOM/ID) (NOM/ID) LENGTH CHANGE K FACTOR (IN) (IN) (FT) (FT) ---- ------ ------ --------------- --------------- --------- --------- -------- LINK EN1 ENTR 3.068 3.068 0.0 0.0 0.5 LINK PIP0 PIPE 3.068 3.068 4.0 0.0 LINK PMP1 PUMP 0.0 0.0 LINK PIP1 PIPE 3.068 3.068 30.0 0.0 LINK GAT1 VALV 3.068 3.000 0.0 0.0 13.0 LINK BEN1 BEND 3.000 0.0 0.0 30.0 LINK PIP2 PIPE 3.068 3.068 10.0 10.0 LINK BEN2 BEND 3.000 0.0 0.0 30.0 LINK PIP3 PIPE 3.068 3.068 70.0 0.0 LINK BEN3 BEND 3.000 0.0 0.0 30.0 LINK PIP4 PIPE 3.068 3.068 30.0 30.0 LINK BEN4 BEND 3.000 0.0 0.0 30.0 LINK EX1 EXIT 3.068 3.068 0.0 0.0 1.0

This report shows velocities and pressure drops for all flow devices. By default, the report appears on PIPEPHASE output. You may suppress it by specifying the SUMM=OLD option on the PRINT statement.

BASE CASE VELOCITY SUMMARY PRESSURE DEVICE DEVICE MIXTURE VELOCITY CRITICAL GRADIENT PRESSURE LINK NAME TYPE (INLET/OUTLET) VELOCITY (INLET/OUTLET) DROP (FPS) (FPS) (PSIFT) (PSIG) ---- ------ ------ ---------------- -------- -------------- -------- LINK EN1 ENTR LINK PIP0 PIPE 4.41 4.41 0.00 -7.3E-3 -7.3E-3 -2.932E-2 LINK PMP1 PUMP LINK PIP1 PIPE 4.41 4.41 0.00 -7.3E-3 -7.3E-3 -0.2 LINK GAT1 VALV LINK BEN1 BEND LINK PIP2 PIPE 4.41 4.41 0.00 -0.35 -0.35 -3.5 LINK BEN2 BEND LINK PIP3 PIPE 4.41 4.41 0.00 -7.3E-3 -7.3E-3 -0.5 LINK BEN3 BEND LINK PIP4 PIPE 4.41 4.41 0.00 -0.35 -0.35 -10.4 LINK BEN4 BEND LINK EX1 EXIT

5-22 Results

Results Summary

Link Device Detail Report

Invoking DEVICE=PART or DEVICE=FULL on the PRINT statement in the General Data Category of input produces a series of detailed link reports. If the user specifies the PRINT option on any individual LINK statements, detailed reports will be produced for those links only.

This report shows the rate, pressure, and temperature for each flow device. By default, the report appears on every PIPEPHASE output. You may suppress it by specifying the SUMM=OLD option on the PRINT statement.

BASE CASE RESULTS SUMMARY DEVICE DEVICE MIXTURE PRESSURE TEMPERATURE QUALITYLINK NAME TYPE FLOW RATE INLET/OUTLET INLET/OUTLET INLET/OUTLET (GPM) (PSIG) (F) (FRAC)---- ------ ------ --------- ----------------- ----------------- ------------ LINK EN1 ENTR LINK PIP0 PIPE 101.68 -4.72E-2 -7.66E-2 104.00 104.00 0.000 0.000 LINK PMP1 PUMP LINK PIP1 PIPE 101.68 30.0 29.8 104.00 104.00 0.000 0.000 LINK GAT1 VALV LINK BEN1 BEND LINK PIP2 PIPE 101.68 29.7 26.2 104.00 104.00 0.000 0.000 LINK BEN2 BEND LINK PIP3 PIPE 101.68 26.2 25.6 104.00 104.00 0.000 0.000 LINK BEN3 BEND LINK PIP4 PIPE 101.68 25.6 15.2 104.00 104.00 0.000 0.000 LINK BEN4 BEND LINK EX1 EXIT


Pressure and Temperature Report

This report is produced with the DEVICE=PART or DEVICE=FULL option.

For some fittings, you will see the entries RES COEFF, which is the resistance coefficient and 2PHASE MULT, which is the two-phase multiplier applied to the resistance coefficient. The entry FL is an abbreviation for flow and has the associated entry SU for subcritical or CR for critical.

BASE CASE LINK "LINK" DEVICE DETAIL REPORT PRESSURE AND TEMPERATURE REPORT ------------------------------- DEVICE MWD OR TVD NAME LENGTH I OR AND SEGM INSIDE FROM & ELEV CALC CALC OVERALL AMB TYPE NO DIAM. INLET O CHNG PRESS TEMP U-FACT TEMP (IN) (FT) (FT) (PSIG) (F) (BTU/ (F) HRFT2F) ------ ---- ------ --------- - -------- ------- ------ ------- ------ EN1 0000 3.068 0.0 I 0.0 4.10E-3 104.0 RES COEF 2PHASE MULT FL (ENTR) 0.0 O 0.0 -4.7E-2 104.0 0.5000 1.0000 SU PIP0 0000 3.068 0.0 I 0.0 -4.7E-2 104.0 80.0 (PIPE) 0001 1.0 0.0 -5.5E-2 104.0 287.596 80.0 0002 2.0 0.0 -6.2E-2 104.0 287.596 80.0 0003 3.0 0.0 -6.9E-2 104.0 287.596 80.0 0004 4.0 O 0.0 -7.7E-2 104.0 287.596 80.0 PMP1 0000 0.0 I 0.0 -7.7E-2 104.0 AVG.POWER/STAGE HP (PUMP) AVAILABLE 4.1 REQUIRED 2.0 SPEED(RPM) 0.0000 0.0 O 0.0 30.0 104.0 EFFICIENCY 0.90 PIP1 0000 3.068 0.0 I 0.0 30.0 104.0 80.0 (PIPE) 0001 7.5 0.0 29.9 104.0 287.596 80.0 0002 15.0 0.0 29.9 104.0 287.596 80.0 0003 22.5 0.0 29.8 104.0 287.596 80.0 0004 30.0 O 0.0 29.8 104.0 287.596 80.0 GAT1 0000 3.068 0.0 I 0.0 29.8 104.0 RES COEF 2PHASE MULT FL (VALV) 3.000 0.0 O 0.0 29.8 104.0 0.2905 1.0000 SU BEN1 0000 3.000 0.0 I 0.0 29.8 104.0 RES COEF 2PHASE MULT FL (BEND) 0.0 O 0.0 29.7 104.0 0.5355 1.0000 SU PIP2 0000 3.068 0.0 I 0.0 29.7 104.0 80.0 (PIPE) 0001 2.5 2.5 28.8 104.0 287.596 80.0 0002 5.0 2.5 28.0 104.0 287.596 80.0 0003 7.5 2.5 27.1 104.0 287.596 80.0 0004 10.0 O 2.5 26.2 104.0 287.596 80.0 BEN2 0000 3.000 0.0 I 0.0 26.2 104.0 RES COEF 2PHASE MULT FL (BEND) 0.0 O 0.0 26.2 104.0 0.5355 1.0000 SU PIP3 0000 3.068 0.0 I 0.0 26.2 104.0 80.0 (PIPE) 0001 17.5 0.0 26.0 104.0 287.596 80.0 0002 35.0 0.0 25.9 104.0 287.596 80.0 0003 52.5 0.0 25.8 104.0 287.596 80.0 0004 70.0 O 0.0 25.6 104.0 287.596 80.0 BEN3 0000 3.000 0.0 I 0.0 25.6 104.0 RES COEF 2PHASE MULT FL (BEND) 0.0 O 0.0 25.6 104.0 0.5355 1.0000 SU PIP4 0000 3.068 0.0 I 0.0 25.6 104.0 80.0 (PIPE) 0001 7.5 7.5 23.0 104.0 287.596 80.0 0002 15.0 7.5 20.4 104.0 287.596 80.0 0003 22.5 7.5 17.8 104.0 287.596 80.0 0004 30.0 O 7.5 15.2 104.0 287.596 80.0 BEN4 0000 3.000 0.0 I 0.0 15.2 104.0 RES COEF 2PHASE MULT FL (BEND) 0.0 O 0.0 15.1 104.0 0.5355 1.0000 SU EX1 0000 3.068 0.0 I 0.0 15.1 104.0 RES COEF 2PHASE MULT FL (EXIT) 0.0 O 0.0 15.0 104.0 1.0000 1.0000 SU


5-24 Results

Pressure and Temperature Plots

Plots are produced for each link when PLOT=FULL is present on the PRINT statement. A temperature plot is also generated (not shown here). The plots are produced with the DEVICE=PART and DEVICE=FULL options.

SURFACE PRESSURE PLOT FOR LINK 30.0 +-PPPPPPPPPPPPP---+-----+-----+-----+-----+-----+-----+-----+ | P | P | | | | | P | P | | | | | P | P | | | | 27.0 + P | P | | | + | P | PPPPPPPPPPPPPPPPPP| | | | P | | PPPPPPPPPPP | | | P | | | P| | 24.0 +-P---------+-----------+-----------+-----------P-----------+ | P | | | |P | | P | | | | P | | P | | | | P | P 21.0 + P | | | | P + R | P | | | | P | E | P | | | | P | S | P | | | | P | S 18.0 +-P---------+-----------+-----------+-----------+------P----+ U | P | | | | P | R | P | | | | P | E | P | | | | P | 15.0 + P | | | | P + | P | | | | | | P | | | | | | P | | | | | P 12.0 +-P---------+-----------+-----------+-----------+-----------+ S | P | | | | | I | P | | | | | G | P | | | | | 9.0 + P | | | | + | P | | | | | | P | | | | | | P | | | | | 6.0 +-P---------+-----------+-----------+-----------+-----------+ | P | | | | | | P | | | | | | P | | | | | 3.0 + P | | | | + | P | | | | | | P | | | | | | P | | | | | 0.0 PPP---+-----+-----+-----+-----+-----+-----+-----+-----+-----+ 0.0 30.0 60.0 90.0 120.0 150.0 DIST. FROM 1ST SURFACE DEVICE INLET FT



Phase Envelope Summary

This report is produced for compositional fluids when the PLOT=FULL option is present on the PRINT statement. The report is produced with the DEVICE=PART and DEVICE=FULL options.

PHASE ENVELOPE SUMMARY (USING SRK) ---------------------------------- TEMPERATURE PRESSURE F PSIG DESCRIPTION --- ----------- ----------- ---------------------------------------- 1 846.01 0.000 DEW POINT 2 882.53 9.534 DEW POINT 3 913.32 21.450 DEW POINT 4 945.27 39.228 DEW POINT 5 977.91 65.749 DEW POINT 6 1010.23 105.313 DEW POINT 7 1010.86 106.263 INTERPOLATED FROM SPECIFIED TEMP OR PRES 8 1015.73 114.004 INTERPOLATED FROM SPECIFIED TEMP OR PRES 9 1040.28 164.337 DEW POINT 10 1063.78 252.390 DEW POINT 11 1071.09 339.714 CRICONDENTHERM 12 1069.31 383.749 DEW POINT 13 1053.24 471.965 DEW POINT 14 1034.19 517.456 DEW POINT 15 1023.02 534.712 CRITICAL POINT 16 1011.92 547.550 BUBBLE POINT 17 982.98 567.154 BUBBLE POINT 18 953.39 572.792 CRICONDENBAR 19 894.20 556.061 BUBBLE POINT 20 834.90 515.069 BUBBLE POINT 21 777.18 460.866 BUBBLE POINT 22 725.73 405.645 BUBBLE POINT 23 679.63 353.606 BUBBLE POINT 24 637.97 306.327 BUBBLE POINT 25 599.99 264.189 BUBBLE POINT 26 565.08 227.043 BUBBLE POINT 27 532.78 194.523 BUBBLE POINT 28 502.72 166.185 BUBBLE POINT 29 474.63 141.573 BUBBLE POINT 30 448.28 120.252 BUBBLE POINT 31 440.12 114.004 INTERPOLATED FROM SPECIFIED TEMP OR PRES 32 429.67 106.263 INTERPOLATED FROM SPECIFIED TEMP OR PRES 33 400.12 85.907 BUBBLE POINT 34 378.03 72.189 BUBBLE POINT 35 357.12 60.372 BUBBLE POINT 36 337.29 50.201 BUBBLE POINT 37 318.48 41.449 BUBBLE POINT 38 300.59 33.920 BUBBLE POINT 39 283.58 27.442 BUBBLE POINT 40 267.37 21.869 BUBBLE POINT 41 237.18 12.937 BUBBLE POINT 42 209.63 6.302 BUBBLE POINT 43 172.61 -0.632 BUBBLE POINT


5-26 Results

Phase Envelope Plot

This plot is produced for compositional fluids when the PLOT=FULL option is present on the PRINT statement. The plot is produced with the DEVICE=PART and DEVICE=FULL options.

P H A S E E N V E L O P E P 750.+-----+-----+-----+-----+-----+-----+-----+-----+-----+-----+ : : : : : : R : : : : : : : : : : : : E 675.+ : : : : + : : : : : : S : : : : : : : : : : : : S 600.+-----------+-----------+-----------+-----------+-----------+ : : : : P : : U : : : : B B: : : : : : :C : R 525.+ : : : : D + : : : : B : : E : : : : : : : : : :B : D : 450.+-----------+-----------+-----------+-----------+-----------+ P : : : : : : S : : : B: : : I : : : : : : G 375.+ : : : : D + : : : B : : : : : : : : T : : : : : : : 300.+-----------+-----------+------B----+-----------+-----------+ : : : : : : : : : B : : : : : : : : D : 225.+ : : B : : + : : : : : : : : : B : : : : : B : : D : 150.+-----------+----------B+-----------+-----------+-----------+ : : : : : : : X X : IB : : DI : : : B : : : : 75.+ : B : : D: + : : BB : : : : : : BB : : D : : : B:BB : : D D : : 0.+-----+-B-B-+-----+-----+-----+-----+----D+-----+-----+-----+ 0. 125. 250. 375. 500. 625. 750. 875. 1000. 1125. 1250. T E M P E R A T U R E F I = INTERPOLATED B = BUBBLE D = DEW X = TRAVERSE T = T EXTREMUM P = P EXTREMUM C = CRITICAL



Holdup and Velocity Report

The T-D FLOW REGM column heading refers to the Taitel-Dukler-Barnea flow regime. The report is produced with the DEVICE=PART and DEVICE=FULL options

HOLDUP AND VELOCITY DETAIL REPORT --------------------------------- DEVICE NAME ---LIQUID HOLDUP--- SUPERFICIAL T-D AND SEG. NO LIQ GAS MIX . FLOW FLOW SONIC TYPE NO. SLIP SLIP TOTAL VEL VEL VEL REGM REGM VEL (AGAL) (FPS) (FPS) (FPS) (FPS) ------ ---- ----- ----- -------- ------- ------- ------- ---- ---- ------- (ENTR) 0000 EN1 0001 PIP0 0000 (PIPE) 0001 1.00 1.00 3.840E-1 4.41 0.00 4.41 DIST 1-PH 0.00 0002 1.00 1.00 7.681E-1 4.41 0.00 4.41 DIST 1-PH 0.00 0003 1.00 1.00 1. 4.41 0.00 4.41 DIST 1-PH 0.00 0004 1.00 1.00 2. 4.41 0.00 4.41 DIST 1-PH 0.00 (PUMP) 0000 PMP1 0001 PIP1 0000 (PIPE) 0001 1.00 1.00 4. 4.41 0.00 4.41 ---- 1-PH 0.00 0002 1.00 1.00 7. 4.41 0.00 4.41 ---- 1-PH 0.00 0003 1.00 1.00 10. 4.41 0.00 4.41 ---- 1-PH 0.00 0004 1.00 1.00 13. 4.41 0.00 4.41 ---- 1-PH 0.00 (VALV) 0000 GAT1 0001 (BEND) 0000 BEN1 0001 PIP2 0000 (PIPE) 0001 1.00 1.00 14. 4.41 0.00 4.41 DIST 1-PH 0.00 0002 1.00 1.00 15. 4.41 0.00 4.41 DIST 1-PH 0.00 0003 1.00 1.00 16. 4.41 0.00 4.41 DIST 1-PH 0.00 0004 1.00 1.00 17. 4.41 0.00 4.41 DIST 1-PH 0.00 (BEND) 0000 BEN2 0001 PIP3 0000 (PIPE) 0001 1.00 1.00 24. 4.41 0.00 4.41 DIST 1-PH 0.00 0002 1.00 1.00 30. 4.41 0.00 4.41 DIST 1-PH 0.00 0003 1.00 1.00 37. 4.41 0.00 4.41 DIST 1-PH 0.00 0004 1.00 1.00 44. 4.41 0.00 4.41 DIST 1-PH 0.00 (BEND) 0000 BEN3 0001 PIP4 0000 (PIPE) 0001 1.00 1.00 47. 4.41 0.00 4.41 DIST 1-PH 0.00 0002 1.00 1.00 50. 4.41 0.00 4.41 DIST 1-PH 0.00 0003 1.00 1.00 52. 4.41 0.00 4.41 DIST 1-PH 0.00 0004 1.00 1.00 55. 4.41 0.00 4.41 DIST 1-PH 0.00 (BEND) 0000


5-28 Results

Pressure Gradient Detail Report

DEVICE=FULL is required to produce this report.

PRESSURE GRADIENT DETAIL REPORT ------------------------------- DEVICE NAME AND SEGM. --PRESSURE GRADIENT---- ---PRESSURE DROP--- TYPE NO: FRIC ELEV TOTAL FRIC ELEV (PSIFT) (PSIFT) (PSIFT) (PSIG) (PSIG) ------ ---- -------- -------- -------- -------- -------- EN1 0000 (ENTR) 0001 PIP0 0000 (PIPE) 0001 -0.0073 0.0000 -0.0073 -7.33E-3 0.0 0002 -0.0073 0.0000 -0.0073 -7.33E-3 0.0 0003 -0.0073 0.0000 -0.0073 -7.33E-3 0.0 0004 -0.0073 0.0000 -0.0073 -7.33E-3 0.0 (PUMP) 0000 PMP1 0001 PIP1 0000 (PIPE) 0001 -0.0073 0.0000 -0.0073 -5.50E-2 0.0 0002 -0.0073 0.0000 -0.0073 -5.50E-2 0.0 0003 -0.0073 0.0000 -0.0073 -5.50E-2 0.0 0004 -0.0073 0.0000 -0.0073 -5.50E-2 0.0 (VALV) 0000 GAT1 0001 (BEND) 0000 BEN1 0001 PIP2 0000 (PIPE) 0001 -0.0073 -0.3394 -0.3467 -1.83E-2 -0.8 0002 -0.0073 -0.3394 -0.3467 -1.83E-2 -0.8 0003 -0.0073 -0.3394 -0.3467 -1.83E-2 -0.8 0004 -0.0073 -0.3394 -0.3467 -1.83E-2 -0.8 (BEND) 0000 BEN2 0001 PIP3 0000



Taitel-Dukler-Barnea Flow Regime Map

Link Property Detail Report

Note: This option can generate very large output files.

The DEVICE=PART or DEVICE=FULL entry is required together with the MAP=TAITEL option to produce this report.The characters on the report indicate the type of flow as follows: I = intermittent flowA = annular flowD = dispersed bubbleW = stratified wavyS = stratified smooth

!+----------------+-----------------+----------------+-------+! 20.00+ DDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDD AAAAAAAAA+ ! DDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDD AAAAAAAAAA! ! DDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDD AAAAAAAAAAA! ! DDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDDD AAAAAAAAAAAAA! 10.00+ DDDDDDDDDDDDDDDDDDDDDDDDDD IIIIIIIIIIIIIIIIII AAAAAAAAAAAAAA+ ! DDDDDDDDDDDDDDDDDD IIIIIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAA! ! DDDDDDDDDDD IIIIIIIIIIIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAA! ! DDDDD IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAAAA! ! IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAAAAA! ! IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAAAAAA! ! IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAAAAAAA! ! IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAAAAAAAAA! ! IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAAAAAAAAAA! ! IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII AAA+AAAAAAAAAAAAAAAAAAAAA! ! IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAAAAAAAAAAAA! ! IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAA! ! IIIIIIIIIIIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAA! ! IIIIIIIIIIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAA! 1.00+ IIIIIIIIIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAAA+ ! IIIIIIIIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAA! ! IIIIIIIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAA! ! IIIIIIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAA! ! IIIIIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAA! ! IIIIIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAA! ! IIIIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAA! VSL ! IIIIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAA! ! IIIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAA! ! IIIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAA! ! IIIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAA! ! IIIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAA! ! IIIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAA! 0.10+ IIIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAA+ ! IIIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAA! ! IIIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAA! ! IIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAA! ! IIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAA! ! IIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAA! ! IIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAA! ! IIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAA! ! IIIIIIIIIIIIIIIIIIIIII AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAAA! ! IIIIIIIIIIIIIIIIIIIIII AAA W AAAAAAAAAAAAAAAAAAAAAAAAAAAAAAA! ! IIIIIIIIIIIIIIIIIIIIII AAA WW AAAAAAAAAAAAAAAAAAAAAAAAAAAAAA! ! IIIIIIIIIIIIIIIIIIIIII AAA WW AAAAAAAAAAAAAAAAAAAAAAAAAAAAAA! ! IIIIIIIIIIIIIIIIIIIIII AAA WWW AAAAAAAAAAAAAAAAAAAAAAAAAAAAA! ! IIIIIIIIIIIIIIIIIIIIII AAA WWW AAAAAAAAAAAAAAAAAAAAAAAAAAAAA! 0.01+ IIIIIIIIIIIIIIIIIIIIII AAA WWW AAAAAAAAAAAAAAAAAAAAAAAAAAAAA+ !+----------------+-----------------+----------------+-------+! 0.1 1.0 10.0 100.0 300.0 VSG VSL = SUPERFICIAL LIQUID VELOCITY (MPS) VSG = SUPERFICIAL GAS VELOCITY (MPS) + = OPERATING POINT PRESSURE= 25.0061(BAR) TEMP: = 101.1447(C) ANGLE = 0.6878(DEG)


5-30 Results

Viscosity and Density Results

Friction and Surface Tension Results

Detailed property tables for any or all links are produced by specifying the PROPERTY=PART or PROPERTY=FULL options.

BASE CASE LINK "1 " PROPERTY DETAIL REPORT VISCOSITY AND DENSITY RESULTS ----------------------------- DEVICE NAME AND SEGM ----------VISCOSITY---------- ------------DENSITY------------ TYPE NO OIL LIQ VAP LIQ VAP SLIP NO-SLIP (CP) (CP) (CP) (LB/CF) (LB/CF) (LB/CF) (LB/CF) ------ ---- --------- --------- --------- ------- ------- ------- ------- Z001 0000 (PIPE) 0001 2.305 2.305 0.000 54.372 0.000 54.372 54.372 Z002 0000 (TEE ) 0001 Z003 0000 (PIPE) 0001 2.303 2.303 0.000 54.370 0.000 54.370 54.370 E1 0000 (DPDT) 0001 Z005 0000 (PIPE) 0001 1.583 1.583 0.000 53.416 0.000 53.416 53.416 Z006 0000 (VENT) 0001 Z007 0000 (CONT) 0001 Z008 0000 (PIPE) 0001 1.582 1.582 0.000 53.415 0.000 53.415 53.415


This report shows the friction factor and the parameters used to calculate it. The report is produced by specifying the PROPERTY=PART or PROPERTY=FULL options.

FRICTION AND SURFACE TENSION RESULTS ------------------------------------ DEVICE NAME LIQ AND SEGM --------------FRICTION------------ FRIC. REYNOLDS SURFACE TYPE NUM. DENSITY VELO ID. VISCOSITY FACTOR NUMBER TENSION (LB/CF) (FPS) (IN) (CP) (DN/CM) ------ ---- ------- ------- -------- --------- -------- -------- -------- Z001 0000 (PIPE) 0001 54.372 9.76 12.000 2.305 0.0156 3.4248E5 29.83 Z002 0000 (TEE ) 0001 Z003 0000 (PIPE) 0001 54.370 14.05 10.000 2.303 0.0155 4.1134E5 29.83 E1 0000 (DPDT) 0001 Z005 0000 (PIPE) 0001 53.416 9.93 12.000 1.583 0.0150 4.9879E5 27.87 Z006 0000 (VENT) 0001 Z007 0000 (CONT) 0001 Z008 0000 (PIPE) 0001 53.415 14.30 10.000 1.582 0.0150 5.9868E5 27.87


Heat Transfer Calculations

PROPERTY=FULL must be specified to produce this report.The HYD column indicates whether or not hydrates can form:N - not in hydrate regionI - type I hydrates formed II - type II hydrates formed U - unable to predictHW - in hydrate region but not enough free water presentP - Hydrate region but insufficient free waterPW - Water & Hydrates but not enough waterNW - Water & Hydrate formationHW - Water & Hydrate

HEAT TRANSFER CALCULATIONS -------------------------- DEVICE FLUID NAME THERMAL ---------THERMAL RESISTANCE------- ----ENTHALPY---- HYD AND SEGM CONDUCT- INSIDE INSULAT- SURROUN- (TYPE) NO: IVITY FILM PIPE ION DING LIQ VAP (KCMC) (HR-M2- (HR-M2- (HR-M2- (HR-M2- (KCALKG) (KCALKG) C/KCAL) C/KCAL) C/KCAL) C/KCAL) ------ ---- -------- -------- -------- -------- -------- -------- -------- -- (PIPE) 0001 0.045 0.0000 0.0000 0.0000 0.0000 0.000 55.712 N 0002 0.045 0.0005 0.0002 0.0000 0.0534 0.000 53.112 N 0003 0.045 0.0005 0.0002 0.0000 0.0534 0.000 50.225 N 0003 0.045 0.0000 0.0000 0.0000 0.0000 0.000 50.225 N 0004 0.046 0.0005 0.0002 0.0000 0.0534 0.000 47.785 N 0005 0.046 0.0005 0.0002 0.0000 0.0534 0.000 44.759 N 0006 0.046 0.0005 0.0002 0.0000 0.0534 29.174 42.169 N 0007 0.047 0.0005 0.0002 0.0000 0.0534 27.765 39.939 N 0008 0.048 0.0005 0.0002 0.0000 0.0534 26.494 37.990 N 0009 0.048 0.0005 0.0002 0.0000 0.0534 25.338 36.305 N 0010 0.049 0.0004 0.0002 0.0000 0.0534 24.271 34.866 N 0011 0.050 0.0004 0.0002 0.0000 0.0534 23.274 33.658 N 0012 0.051 0.0004 0.0002 0.0000 0.0534 22.774 33.099 N 0012 0.051 0.0000 0.0000 0.0000 0.0000 22.774 33.099 N 0013 0.052 0.0004 0.0002 0.0000 0.0534 22.331 32.633 N 0014 0.053 0.0004 0.0002 0.0000 0.0534 21.480 31.815 N 0015 0.054 0.0004 0.0002 0.0000 0.0534 20.663 31.160 N 0016 0.055 0.0004 0.0002 0.0000 0.0534 19.878 30.660 N 0017 0.056 0.0004 0.0002 0.0000 0.0534 19.122 30.296 N 0018 0.056 0.0004 0.0002 0.0000 0.0534 18.603 30.106 N 0018 0.056 0.0000 0.0000 0.0000 0.0000 18.603 30.106 N 0019 0.056 0.0003 0.0002 0.0000 0.0534 18.026 30.051 P 0020 0.057 0.0003 0.0002 0.0000 0.0534 17.234 30.077 P P011 0000 (PIPE) 0001 0.057 0.0003 0.0002 0.0000 0.0534 16.819 30.112 P S013 0000 (SEPR) 0001


5-32 Results

Slug Report

SLUG is specified with DEVICE=PART or DEVICE=FULL to produce these reports. The Brill, Norris or Scott method may be used for the slug calculations.The report will not appear if the flow is not two-phase or if conditions are outside the range of the correlation.

Note: With DEVICE=FULL, you will get output for the total liquid in slug unit. This is equal to the Slug volume + Tail Volume + Total holdup associated with the slug.

SLUG SIZING AND SLUG DELIVERY MODEL (BRILL ET AL) ------------------------------------ PREDICTED MEAN SLUG LENGTH = 635.4 M THE PREDICTED MAX SLUG LENGTH FROM CORRELATION IS TOO LARGE ADJUSTED MEAN SLUG LENGTH = 312.5 M 84.1300 PERCENT PROBABILITY THAT SLUG LENGTH IS .LE. 515.2 M 97.7200 PERCENT PROBABILITY THAT SLUG LENGTH IS .LE. 849.3 M 99.8600 PERCENT PROBABILITY THAT SLUG LENGTH IS .LE. 1393.1 M 99.9900 PERCENT PROBABILITY THAT SLUG LENGTH IS .LE. 2006.7 M 99.9999 PERCENT PROBABILITY THAT SLUG LENGTH IS .LE. 3365.5 M SLUG DELIVERY ------------- THE GAS BUBBLE VELOCITY IS = 7.2 M/SEC THE LIQUID FILM VELOCITY IS = 0.9 M/SEC THE GAS VELOCITY IS = 6.7 M/SEC 50.0000 PERCENTILE SLUG -------------------------- THE LIQUID SLUG DELIVERY TIME IS= 43.38 SECS SLUG DELIVERY MODEL NOT APPLICABLE 84.1300 PERCENTILE SLUG -------------------------- THE LIQUID SLUG DELIVERY TIME IS= 71.51 SECS SLUG DELIVERY MODEL NOT APPLICABLE 97.7200 PERCENTILE SLUG -------------------------- THE LIQUID SLUG DELIVERY TIME IS= 117.89 SECS SLUG DELIVERY MODEL NOT APPLICABLE 99.8600 PERCENTILE SLUG -------------------------- THE LIQUID SLUG DELIVERY TIME IS= 193.37 SECS SLUG DELIVERY MODEL NOT APPLICABLE 99.9900 PERCENTILE SLUG -------------------------- THE LIQUID SLUG DELIVERY TIME IS= 278.54 SECS SLUG DELIVERY MODEL NOT APPLICABLE 99.9999 PERCENTILE SLUG -------------------------- THE LIQUID SLUG DELIVERY TIME IS= 467.14 SECS SLUG DELIVERY MODEL NOT APPLICABLE *** NOTE: THE STATISTICAL SLUG MODEL IS APPLICABLE IF THE DOWN STREAM END OF THE PIPELINE IS HORIZONTAL OR NEAR HORIZONTAL AND IF UPSTREAM TERRAIN EFFECTS ARE NOT FELT AT THE DELIVERY POINT (END OF THE PIPELINE) IF SLUG OCCURRING REGION IS LESS THAN 4300.182 M SLUG LENGTHS WILL BE SMALLER THAN PREDICTED BY MODEL

SEVERE SLUGGING CALCULATIONS ---------------------------- SEVERE SLUGGING GROUP NUMBER = 6.370 EXPECTED SLUG LENGTH = 32.967 M *** NOTE: SEVERE SLUGGING GROUP NUMBER ANALYSIS IS VALID ONLY IF A PREDOMINANTLY DOWNWARD SLOPING PIPELINE IS FOLLOWED BY A VERTICAL UPWARD PIPE AT THE END OF THE LINK



Case Summary

This report is always produced to summarize case study results. It shows the node pressures, temperatures, and flowrates for each case.

BASE CASE PRESSURE TEMPERATURE FLOW RATE NODE PSIG DEG F LB/HR ---- -------- ----------- --------- FEED 114.0 60.0 1500000.00 J1 0.106E+03 0.100E+03 0.00000E+00 J2 0.926E+02 0.142E+03 0.00000E+00 PROD 87.4 182.4 -1500000.00 CASE STUDY 1 PRESSURE TEMPERATURE FLOW RATE NODE PSIG DEG F LB/HR ---- -------- ----------- --------- FEED 125.0 60.0 1500000.00 J1 0.117E+03 0.100E+03 0.00000E+00 J2 0.104E+03 0.142E+03 0.00000E+00 PROD 98.4 182.4 -1500000.00 CASE STUDY 2 PRESSURE TEMPERATURE FLOW RATE NODE PSIG DEG F LB/HR ---- -------- ----------- --------- FEED 114.0 60.0 1500000.00 J1 0.107E+03 0.100E+03 0.00000E+00 J2 0.932E+02 0.142E+03 0.00000E+00 PROD 88.0 182.4 -1500000.00


5-34 Results

Nodal Analysis (Sensitivity)The only output produced when the nodal analysis feature is used shows comparisons of pressure, temperature, and flowrate at the defined node for the combinations of inflow and outflow parameters. Plots are produced for pressure and temperature (only pressure is shown here). If a well completion zone is included in the analysis, the pressure drop across it is also produced.

SOLUTION NODE IS AT INLET OF DEVICE CHK1 NODAL ANALYSIS 600.0 +----+----+----+----+----+----+----+----+----+----+----+----+ | | | | | | AA | | | | | | AAA | | | | | | | AAA | 540.0 + | | | | AAA + | | | | | AA| | | | | | | AAA | | | | | | | AAA | | 480.0 +---------+---------+---------+--------AAA--------+---------+ | | | | AAAA | | | | | | | AAA | | | | | | AAA | | | 420.0 + | | AAAA | | | + | | | AAA | | | | P | | AAA | | | | R | | AAAA | | | | BBB E 360.0 +---------+-AAA-----+---------+---------+---------+--BBBBB--+ S 111111111***1111111111111111111 | BBBBB | S | AAAA | | |111111111111*****1111111111111 U | AAA | | | BBBBBB | | R 300.0 **2222222222222222222222222222*BBBBBB | | + E | | | BBBBBB|222222222222222222222222222222 | | BBBBBB | | | CCCC 33333333333 BBBBB | | | CCCCCCC | B 240.0 +-------BBB**3333333333333333333333333333333******33333333333 A | BBBBB | | | CCCCCCCCC | | R BBB | | CCCCCCCCCC | | | | | CCCCCCCC | | DDDDDDDDDDD 180.0 + CCCCCCC | | DDDDDDDDDDDDDDD| + | CCCCCC| | DDDDDDDDDD | | | CCCC | DDDDDDDDDD | | | | | DDDDDDDDDD | | | | | 120.0 DDDDD-----+---------+---------+---------+---------+---------+ | | | | | | | | | | | | | | | | | | | | | 60.0 + | | | | | + | | | | | | | | | | | | | | | | | | | | | 0.0 +----+----+----+----+----+----+----+----+----+----+----+----+ 40.0 45.0 50.0 55.0 60.0 65.0 70.0 FLOW RATE (M3/HR) KEY... 1 - 450 BAR 2 - 400 BAR 3 - 350 BAR A - 3 1/2 IN DIA B - 4 IN DIA C - 4 1/2 IN DIA D - 5 IN DIA


Pressure and temperature tabular reports are also produced for both inflow and outflow variables. Only the pressure table is shown here.If a well completion zone is included in the analysis, tabular data for the pressure drop across it are also shown.

SOLUTION NODE IS AT INLET OF DEVICE CHK1 NODE PRESSURES FOR INFLOW VARIABLES (BAR) ----------------------------------- INFLOW VARIABLE RATE --------------- (M3/HR) 450 BAR 400 BAR 350 BAR ------------ ------------ ------------ ------------ 40.00 345.55 298.31 252.33 50.00 340.58 293.29 247.17 60.00 334.56 287.18 240.86 70.00 327.46 279.96 233.36 NODE PRESSURES FOR OUTFLOW VARIABLES (BAR) ------------------------------------ OUTFLOW VARIABLE RATE ---------------- (M3/HR) 3 1/2 IN DIA 4 IN DIA 4 1/2 IN DIA 5 IN DIA ------------ ------------ ------------ ------------ ------------ 40.00 305.95 210.59 154.65 119.39 50.00 390.88 264.47 191.75 146.16 60.00 482.32 320.82 230.05 173.69 70.00 582.13 379.92 269.56 201.94



The final nodal analysis report lists the pressure and flowrate at the inter- sections of the inflow and outflow curves - i.e., the operating points of the system.

SOLUTION NODE IS AT INLET OF DEVICE CHK1 INFLOW-OUTFLOW CURVE INTERSECTION POINTS ---------------------------------------- INFLOW OUTFLOW RATE PRESSURE CASE CASE (M3/HR) (BAR) ----------- ----------- ----------- ----------- 450 BAR 3 1/2 IN DIA 44.41 343.36 4 IN DIA 62.08 333.08 400 BAR 4 IN DIA 54.61 290.47 350 BAR 4 IN DIA 47.07 248.68 4 1/2 IN DIA 62.30 239.13


5-36 Results

Sphering Report

This report follows the liquid slug in front of the sphere.

----------------SLUG ZONE------------------ SLUG SLUG SLUG SLUG EDGE PRESS: EDGE TIME VELO: LENGTH PRESS: DROP DISTANCE (SECS) (FPS) (FT) (PSIA) (PSIA) (FT) ------- ------- --------- ------- ------- --------- 19.0 26.20 20.1 346.5 4.5 514.4 38.0 26.09 40.0 345.6 5.7 1024.7 57.0 26.10 59.8 343.4 6.9 1534.9 76.0 25.99 79.4 342.6 8.1 2038.9 95.0 25.99 99.6 340.4 9.4 2549.1

The slug delivery report starts when the front of the slug reaches the end of the pipeline.

SLUG DELIVERY ------------- PRESS: SLUG SPHERE BEHIND TIME VELOCITY VELOCITY SPHERE (SECS) (FPS) (FPS) (PSIA) ------- -------- -------- ------- 9.8 13.89 13.89 274.9 19.6 13.89 13.89 273.6 29.4 13.89 13.89 272.4 39.2 13.93 13.93 271.3 48.9 13.99 13.99 270.6 58.6 14.05 14.05 269.6 68.3 14.10 14.10 268.6 77.9 14.16 14.16 267.5 87.5 14.21 14.21 266.5 97.1 14.26 14.26 265.4 SLUG DELIVERY TAKES 181.3 SECS.

Finally, the time required for the pipeline to return to steady state is shown.

STEADY STATE NOT REACHED YET. TIME IS 30329.94 SECS. STEADY STATE NOT REACHED YET. TIME IS 30492.76 SECS. STEADY STATE NOT REACHED YET. TIME IS 30655.57 SECS. STEADY STATE NOT REACHED YET. TIME IS 30818.38 SECS. STEADY STATE NOT REACHED YET. TIME IS 30981.19 SECS. STEADY STATE NOT REACHED YET. TIME IS 31144.01 SECS. STEADY STATE FLOW IS RE-ESTABLISHED AFTER 31306.8 SECS



Results Access System

Specifying DATA=FULL on the PRINT statement creates a binary file which can be used by the GUI to produce graphical and tabular reports.

This example shows where the selected link lies on the phase envelope. The hydrate and water saturation curves are also shown.

Note: For Windows GUI users only.

5-38 Results

Chapter 6 Technical Reference

Chapter Contents

About This Chapter . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4An Introduction to Fluid Flow . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4

Basic Fluid Flow Theory . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4The Steady State Flow Process — Single-Phase Fluids . . . . . . . . . . . . . . . . . . . . . . . . . . . 5Laminar and Turbulent Single-phase Flow . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9

Laminar Flow . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9Laminar and Transitional Flow Inside Pipes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10

Turbulent Flow . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11Non-Newtonian Flow . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12Two-Phase Fluid Flow in Pipes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12Liquid & Gas Holdup - Slip & No-Slip. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14Two-Phase Mixture Properties . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15Single and Two-Phase Pressure Drop Correlations in PIPEPHASE. . . . . . . . . . . . . 20

Critical Flow - A Qualitative Description. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 21Single-Phase Flow . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 23Two-Phase Flow . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 24Mechanistic Models. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 24Ansari. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 24Xiao . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 25TACITE. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 25OLGA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 26

Recommendations on Pressure Drop Correlations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 27Solution Algorithms Used in PIPEPHASE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 27

The Calculation Segment and Iteration Methodology . . . . . . . . . . . . . . . . . . . . . . . . . . . 27The Calculation Segment. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 27Default Segment Calculation Procedure . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 28The SHORTPIPE Segment Calculation Procedure . . . . . . . . . . . . . . . . . . . . . . . . . . 30The Single Link Calculation Method . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 32

The Network Calculation Method . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 33Definition of a Network. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 34


Pressure Balance Method . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 34Mass Balance Method . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 34How to Set up a Network Problem . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 35

Fluid Models Used in PIPEPHASE. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 36Non-Compositional Fluid Models . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 36

Single-phase Gas . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 37Gas Compressibility (z) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 37Gas Density (rG ) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 37Gas Viscosity (mG ) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 37Gas Specific Heat Capacity (CpG) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 38

Single-Phase Liquid . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 38Hydrocarbon Liquid Viscosity (ml) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 38

Beggs and Robinson Correlation. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 38Standing Correlation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 38Glaso Correlation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 38Vazquez and Beggs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 39

Oil-water Viscosity (L) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 39Woelflin's Correlation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 39

Water Viscosity (mw) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 41Blackoil (and Other Empirical Methods) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 41Solution Gas-Oil Ratio . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 42

Solution Gas-Water Ratio . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 43Fluid Mixing Rules for Blackoil Models . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 45

Condensate . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 47Steam Model. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 47Compositional Fluid Models . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 48

Accuracy of Compositional Modeling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 48Properties Calculated Using the Compositional Fluid Model. . . . . . . . . . . . . . . . . . 48Equilibrium K-Values (Phase Split) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 48

Enthalpy . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 50Heat Transfer in Flow Devices . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 51

Heat Transfer for Non-Compositional Fluids. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 52Heat Transfer for Compositional Fluids. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 52The Overall Heat Transfer Coefficient (U-value) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 54

Equations used in PIPEPHASE to Calculate Resistances. . . . . . . . . . . . . . . . . . . . . 55Inside film resistance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 55Pipe resistance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 55Insulation resistance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 55Buried surroundings (e.g., soil resistance) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 56Fluid surroundings (e.g., air, water). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 56Additional inside/outside resistance. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 56Radiation film resistance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 56

Partially Buried Pipes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 57Heat Transfer in Wellbores95 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 57

Equipment & Fittings Flow Devices . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 58Electrical Submersible Pump (ESP). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 59Compressor. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 59DPDT Devices . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 60

6-2 Technical Reference

Chokes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 60Single-Phase Gas and Single-Phase Liquid Models . . . . . . . . . . . . . . . . . . . . . . . . . 60Gilbert Family (GF) of choke models . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 62

Algorithm: . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 62Network Solving Algorithm with a GF Choke in Source Link(s) . . . . . . . . . . . 63Network Solving Algorithm with a GF Choke in Internal and Sink Link(s) . . . 63Extensions of the GF Model Applicability. . . . . . . . . . . . . . . . . . . . . . . . . . . . . 64Errors and Warnings. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 64

Other Fluid Models . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 65Check Valves . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 65Heaters and Coolers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 65

Single-Phase Gas and Single-Phase Liquid Models . . . . . . . . . . . . . . . . . . . . . . . . . 65Compositional and Steam Fluid Models . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 65

Separators . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 66Blackoil . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 66Condensate. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 66Compositional . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 66

Fittings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 66Two-Phase Flow Pressure Drop Corrections for Fittings . . . . . . . . . . . . . . . . . . . . . 66

Chisholm Method . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 67Homogeneous Model . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 68Completion . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 68

Converging Network Simulations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 72User Requirements for this Section . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 72General Recommendations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 73

Simulation Input Granularity. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 73Estimates of Pressure and Flowrate. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 73Network Structure and Topology . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 74Maximum Number of Iterations (NM) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 75Iteration History. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 75

Specific Recommendations. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 75Link Shut-Ins (NM) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 75Flowrate Estimation in Links . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 76Guidelines on User-Estimation of Link Flow Rates . . . . . . . . . . . . . . . . . . . . . . . . . 80Recommendations for Networks which Include Loops . . . . . . . . . . . . . . . . . . . . . . 80Other Problems In Network Convergence. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 85Specific Keyword Assistance in Converging Networks . . . . . . . . . . . . . . . . . . . . . . 86

PBAL Algorithm . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 86MBAL Solution Algorithm . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 94

Sub-Network Algorithm . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 95Introduction. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 95

Frequently Asked Questions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 96FAQ 1: What are the merits of the K-factor and K-multiplier in

fitting pressure drops? . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 97FAQ 2: Should one use “equivalent lengths” inside links with two-phase

flow to represent fitting pressure drops? . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 98FAQ 3: How do you explain a pressure recovery over an expansion device? . . . . . . . . 99FAQ 4: Why does PIPEPHASE have two network solution


methods (Flare and Network)?. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 100FAQ 5: What is the relation between discharge coefficients used in valve

sizing and the K-factor used to define pressure drop? . . . . . . . . . . . . . . . . . . . 100FAQ 6: What is the relation between the flow coefficient of a valve (Cv)

and the K-factor for the valve? . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 101FAQ 7: What is the relation between the Joule-Thomson effect

and adiabatic flashing?. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 102FAQ 8: How can I make PIPEPHASE use my own mixture physical

property data in compositional fluid-type simulations? . . . . . . . . . . . . . . . . . 103FAQ 9: How can I increase the speed of execution of a simulation run?. . . . . . . . . . . 110FAQ 10:What are the *.GR1, *.GR2, *.GR3, and *.GR4 files that are

produced when I run PC PIPEPHASE?. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 110Data Transfer System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 111

Procedure for Accessing PRO/II Stream Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 111Extracting Component Data and Temperature for aSource – PRO2 Keyword . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 113Extracting Component Data, Pressure and Temperature for aSource – PR2F Keyword. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 113Extracting Pressure Estimate, Component Data, and Temperature for aSource – PR2E Keyword. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 114Restrictions on the Use of the Stream Data Transfer Facility. . . . . . . . . . . . . . . . . 115

About This Chapter

This chapter provides detailed information regarding the calculation procedures used for all aspects of the PIPEPHASE program. The chapter is not intended to be a complete work on multiphase flow or thermodynamic theory. Instead, it aims to provide sufficient background theory and simulation guidelines so that a user can be more confident in using the program and making better engineering decisions prior to executing the task.

An Introduction to Fluid Flow

Basic Fluid Flow Theory

Except where specified otherwise, the term “fluid” is used in this chapter to denote either a single-phase gas, single-phase liquid, or a multiphase stream comprising a gas phase and one or more liquid phases.

As with any field of scientific analysis, it is worthwhile to take time to understand the fundamentals behind the basic pressure drop equation. This pressure drop equation, which is derived from the general energy equation, is given in its simplest form in equation (6-1):

(6-1)PTOT PELEV PFRIC PACCEL+ +=


A summary of this derivation procedure is provided here for reference purposes.

The Steady State Flow Process — Single-Phase Fluids

A fluid passing from point 1 to point 2, in Figure 6-1 below, must be subject to the general principle of the conservation of energy. This states that, at steady state, the enthalpy of the fluid at point 1, plus any work performed on or by the fluid, plus any heat taken from or added to the fluid, must equal the enthalpy of the fluid at point 2.

Figure 6-1: Conservation of Energy - Fluid Flow in a Simple System

The steady state energy balance equation is shown in equations (6-2a)-(6-2c):

(6-2a)

(6-2b)

(6-2c)

where:

Q = heat added to, or taken away from, the fluid (e.g., by a heat exchanger, or by transfer to or from the surroundings)

Ws = shaft work done on or by the fluid (e.g., by a pump, or in a turbine)

Note: The subscript S is used to distinguish work exchanged by the fluid through a shaft from that work done by the fluid itself on the system in entering and leaving the control volume under study. This is the pV component of equation (6-2c).

U = fluid internal energy

p = fluid pressure

V = fluid specific volume

Energy input to system = Energy output from system

(Heat Exchange + Shaft Work Exchange + Internal Energy +

Fluid Work + Kinetic Energy + Potential Energy)in=

(Internal Energy + Fluid Work + Kinetic Energy + Potential Energy)out

Q Ws U1 p1V1

mv12

2gc---------- mZ1

ggc-----+ + + + + U2 p2V2

mv22

2gc---------- mZ2

ggc-----+ + +=


Changing the basis of equation (6-2c) to that of unit mass, and looking at differential changes rather than macro-system changes results in equation (6-3):

(6-3)

where:

The specific enthalpy change, dh, in a system is defined as:

(6-4a)

Equation (6-4a) can also be written as:

(6-4b)

For a reversible system:

(6-5)

from the Second Law of Thermodynamics, for reversible work, wrev, and heat, qrev:

(6-6)

and

(6-7)

m = fluid mass flowrate

1/gc = proportionality/dimension constant

g = gravitational constant

v = fluid velocity

Z = elevation of the fluid, referenced to one (arbitrary) datum level

u = specific internal energy of the fluid

q = specific heat exchanged

ws = specific shaft work

r = fluid density

du dp--- vdv

gc--------- g

gc-----dZ dq dws+ + + + + 0=

dh du d pV +=

dh du dp---

+=

du1---

dp pd1--- + +=

du dqrev dwrev–=

dwrev pdV=

pd1---

=

dqrev TdS–=


where:

Therefore, equation (6-4a) may be rearranged to make du the subject and equations (6-6) and (6-7) can be substituted into relationship (6-5). The resultant expression may then be directly substituted into equation (6-3), to create equation (6-8):

(6-8)

Equation (6-7) is valid for a truly reversible process. In reality, due to irreversibilities such as friction, there will always be losses inherent in any process. Equation (6-7) for irreversible processes then becomes:

(6-9)

where:

If the assumption is made that there is no shaft work performed by, or on, the fluid (ws=0), then expression (6-9) becomes:

(6-10)

Figure 6-2: Schematic Representation of Piping Inclination

A pipe, inclined at an angle to the horizontal, as shown in Figure 6-2, will effect a change to the vertical dZ term in equation (6-10). Since dZ = dL sin , multiplying equation (6-10) through by/dL gives:

(6-11)

ds = the differential specific entropy change in a system

T = the absolute temperature value at which q is exchanged

Lw = lost friction work

Tds dp

------ dp--- d

p--- vdv

gc--------- g

gc-----dZ dq dws+ + + + +–+ 0=

dq– dLw+ TdS=

dp

------ vdvgc

--------- ggc-----dZ dLw 0=+ + +

dpdL------ vdv

gcdL------------ g

gc----- sin

dLwdL

----------+ + + 0=


Equation (6-11) can then be rearranged and integrated over a pipe length L to give the familiar steady state pressure drop equation (6-12). The resulting equation is known as Bernoulli’s equation for the case of integrating for fluids of constant density, or as Euler’s equation when used for an ideal fluid, where the loss term, (Lw), is set to zero.

(6-12)

When computing the total pressure drop, p, the lost work due to friction must be expressed in more common terms. The loss component from equation (6-11), (dLw/dL), can be more explicitly defined by performing a simple force balance on a section of circular pipe between the wall shear stress (which accounts for the frictional losses) and pressure forces (Figure 6-3).

Figure 6-3: Force Balance on Circular Pipe Section

(6-13)

where:

Equation (6-13) can be written as:

(6-14)

Substituting for dLw into equation (6-15) gives:

(6-15)

tw = shear stress, or shear resistance to flow

di = internal pipe diameter

p– ggc-----L Lw 2

2gc------------------++sin=

p1 p1dpdL------dL–

gcdi

2

4----------------– w di dL=

dpdL------

FRICTION

4gcwdi

---------------- dLwdL

---------- = =

dpdL------ vdv

gcdL------------ g

gc----- sin

4gcwdi

----------------+ + + 0=


For both laminar (streamline) and turbulent flow, a dimensionless friction factor, f, is defined as the ratio of shear stress to the fluid kinetic energy per unit volume:

(6-16)

Equation (6-16) represents one of the original friction factor formulations as defined by Fanning. The Darcy-Weisbach (or Moody1) friction factor, fd, is used in PIPEPHASE and is defined as being four times larger than the Fanning factor:

(6-17)

Note: The superscripts given in the text in this chapter refer to the appropriate entry in C.

Substituting equation (6-17) into the pressure loss component of equation (6-15) gives:

(6-18)

The general pressure drop expression for a single-phase fluid can then be re-written as:

(6-19)

Note: Users of SI or Metric units of measure: The unit of force in SI and Metric unit sets is the Newton. The Newton is defined so as to make the proportionality constant, gc, unity, thus eliminating it from equation (6-19).

Laminar and Turbulent Single-phase Flow

Laminar Flow

At low velocities, a single-phase fluid in pipes flows in one direction, and the velocity within the pipe changes across the plane perpendicular to its axis, from a maximum in the center of the pipe, to zero at the pipe wall. For a circular pipe, the velocity profile is a parabola (see Figure 6-4), where the fluid particles move in straight, parallel paths in layers, or laminae. The term laminar flow is therefore used to describe this condition. In

fFANNING

w

v2

2----------------

2w

v2

----------= =

fd

w

v2

8----------------

8w

v2

----------= =

dpdL------

FRICTIONw

digcAi-----------

fdv2

8gc-------------- di

di2

4----------------- fdv

2

2gcdi--------------= = =

dpdL------– g

gc----- sin

fdv2

2gcdi

-------------- vdvgcdL------------+ +=


laminar flow systems, analytical laws relating shear stress (and hence friction) to the rate of angular deformation may be applied. Since the viscosity of the fluid is dominant in laminar flow, this suppresses any tendency toward turbulent conditions (see below).

Figure 6-4: Laminar Flow in a Circular Pipe

For a laminar flowing fluid, the following equation for the Darcy-Weisbach friction factor can be derived analytically from Poiseuille’s equation:

(6-20)

where:

Laminar and Transitional Flow Inside Pipes

PIPEPHASE incorporates the unified correlation developed by Churchill76 for heat transfer calculations. This correlation spans the laminar and turbulent regions, and it calculates a constant Nusselt number of 4.36 when the Reynolds number falls below 2300. Therefore, the user has no control over the critical Reynolds number below which laminar conditions are applied. In other words, the keyword entry of “LAMINAR=value” has no influence in calculating the heat-transfer coefficient.

However, the Churchill correlation has not been implemented for calculating the friction factor. Therefore, the keyword entry of “LAMINAR=value” will still be used to influence the friction pressure drop calculations.

Reynolds Number

For the benefit of fluid flow studies, a dimensionless value representing the ratio of a fluid’s inertia forces to its viscous forces has been defined. This is known as the Reynolds number, Re, and is commonly utilized as an indication of the turbulence of the fluid. For circular pipes, the Reynolds number is defined as:

(6-21)

= fluid viscosity

fd64vdi-----------=

Revdi

-----------=


This number is used as a basis for many pressure drop- and heat transfer-related correlations.

Turbulent Flow

As the flowrate of a fluid is increased from laminar flow conditions, the fluid particles begin to move randomly in all directions of flow, and in a more haphazard fashion as velocities increase. As the flowrate increases even further, the fluctuations in the behavior of the particles becomes more significant, and the flow is termed turbulent.

Typically, the transition between laminar flow and full turbulent flow occurs over a region between Reynolds numbers of 2000 and 3000.

Figure 6-5: Turbulent Flow in a Circular Pipe

It then becomes impossible to track the movement of an individual particle, and the velocity profile of the fluid becomes correspondingly more uniform, or flat, in the plane perpendicular to the axis of the pipe (see Figure 6-5). It is not possible to predict the friction factor associated with turbulent flow using the same analytical methods as for laminar conditions. To better predict friction factors under turbulent conditions, experimental observations are combined with the previous theoretical fluid flow relationships. Friction factors for turbulent flow are then defined empirically – usually in terms of the Reynolds number, Re.

The Darcy-Weisbach friction factor, fd, has been found to be a function of Reynolds number alone in the case of smooth pipe walls, and for rough pipe walls as a function of both Reynolds number and the relative roughness of the pipe inside wall. Relative roughness is a dimensionless quantity, and is thought to be more indicative than absolute pipe roughness on the effect on pressure gradient.

The relative roughness is usually abbreviated in its equation form, /d, where is the absolute pipe mean roughness, and d is the (smooth) pipe inside diameter. An example of a friction factor expression for single-phase flow in circular pipes with rough walls is shown in equation (6-22), which was developed by Colebrook2:

(6-22)1

fd

--------- 1.74 2log102di----- 18.7

Re fd

----------------+

–=


To solve these types of equations usually requires an iterative procedure to determine fd. In standard texts these equations are represented as graphs of friction factor versus Reynolds number, containing lines of constant /d (see Figure 6-6).

Figure 6-6: Friction Factor Chart (Semi-Log fd vs Log Re) – after Moody

Non-Newtonian Flow

All previous and subsequent discussions in this chapter refer to so-called “Newtonian” fluids (where shear stresses are postulated to be directly proportional to the time rate of deformation of a fluid element). Non-Newtonian fluids do not obey newtonian flow dynamics, and include common fluids such as some oil/water mixtures, mud, cement, and a variety of plant-processed slurry streams. Non-Newtonian fluids can behave in different ways in response to a constant shear force - such as decreasing viscosity (so-called pseudoplastic or thixotropic [for time-dependent responses] fluids) or increasing viscosity (so-called dilatant or rheopectic [for time-dependent responses] fluids). Non-Newtonian fluids can be modeled in PIPEPHASE currently only by specifying an appropriate user-defined pressure drop method (see Chapter 3, Input Reference).

Two-Phase Fluid Flow in Pipes

Up until this point in our discussion of fluid flow, all assumptions have been for single-phase fluids. In the topics covering laminar and turbulent flow, it was seen that fluid flow theory can take us only as far as single-phase, laminar flow. Once the laminar to turbulent flow transition is made for single-phase fluids, modeling the flow becomes complex. Fluid flow theory then enters a gray area where empirical correlations and experimental observation account for a large portion of key areas in the prediction of pressure drop. All salient equations describing two-phase flow build on existing single-phase equation forms. However, they are far more empirical than their single-phase equivalents due to the complex nature of multiphase flow.


In single-phase laminar flow, fluid properties such as density, , and viscosity, , must be known prior to any pressure drop formulation being applied (see equations (6-19) and (6-20)). This concept is relatively simple for a single-phase fluid – simple temperature- and pressure-dependent correlations and mixing rules can be applied with confidence for all but the heaviest and non-ideal of fluids. However, the definition and meaning of two-phase fluid physical properties such as density or viscosity requires further discussion.

Clearly some type of viscosity and density must be used in the overall pressure drop expression, and since the only physical data available to the researcher and engineer are viscosities of both phases in isolation, a suitable mixing rule for the two-phases must be formulated. Before this can be accomplished, there must be a knowledge of the relative amounts of both phases existing at the point of interest in the pipe. The term holdup is commonly used to describe this quantity.

Liquid Holdup and Superficial Velocities

Two quantities are used extensively in two-phase flow analyses, the superficial velocity of each phase, and the liquid or gas holdup.

The superficial velocity is defined as the velocity at which one-phase would travel if it alone occupied the whole pipe, and can be calculated from volumetric flowrates:

(6-23a)

(6-23b)

where:

subscripts G and L refer to the gas (vapor) and liquid phase respectively

The fluid mixture velocity is then defined as the velocity of the total mixture, and can be shown to be equal to the sum of the component superficial velocities:

(6-24a)

(6-24b)

where:

subscript M refers to the mixture

q = volumetric flowrate of the phase

A = cross-sectional area of the pipe

s = superficial velocity of the phase

vsL

qL

A----- for the liquid =

vsG

qG

A------ for the gas =

M

qL qG+

A-------------------=

M sLsG

+=


Liquid & Gas Holdup - Slip & No-Slip

Liquid holdup, HL, is defined as the fraction of the pipe’s cross-sectional area occupied by liquid (see Figure 6-7):

(6-25)

For the complementary gas holdup:

(6-26)

For a given steady-state “snapshot” of a two-phase fluid flowing in a pipe, there can be two feasible liquid holdup scenarios – slip liquid holdup (where the gas and liquid are traveling at different velocities) and no-slip liquid holdup (where both phases are actually traveling at the same speed). These concepts are important in the study of two-phase flow systems, and will be utilized fully when describing two-phase pressure drop correlations. In either scenario the liquid holdup varies from a value of one for all liquid flow, to zero for all gas flow. The term positive slip is used to describe situations where the gas is traveling faster than the liquid, and negative slip for the reverse situation.

Figure 6-7: Liquid and Vapor Holdup

The slip velocity is defined as the difference between the actual gas and liquid velocities:

(6-27)

Now,

(6-28a)

(6-28b)

HL

AL

A------=

HG

AG

A-------=

s G L–=

G

qG

AG-------=

L

qL

AL------=


Then from equations (6-23a), (6-23b), (6-25) and (6-26) it is simple to show that, for cases of no-slip w hereG = L:

(6-29)

where:

Therefore, the no-slip liquid holdup can be shown to be a function only of the superficial velocities of each phase, and is thus simple to calculate if the volumetric flowrate of each phase is known.

In a majority of two-phase flow situations, however, the no-slip assumption is false, and should not be used for reasonable pressure drop predictions. This is typically because of the flow pattern, and/or the topology of the piping system (which can encourage slip conditions through inclined and vertical pipe sections). In these cases, liquid holdups must be calculated from empirical correlations.

Once the liquid holdup value has been determined for the segment of piping under study, then its first use is in calculating actual gas and liquid velocities from their corresponding superficial values (from equations (6-26), (6-28a) and (6-28b)):

(6-30)

Two-Phase Mixture Properties

A two-phase fluid mixture density, m, can be defined using the holdup as the weighting factor between both phases. Although some researchers use different formulations, equation (6-31) represents one of the most common relationships for density used to calculate the elevation term in the pressure drop equation (in this equation HL refers to either the slip or no-slip liquid holdup):

(6-31)

The viscosity of a fluid is used in all pressure drop correlations, at least in the determination of the friction factor, fd, via the Reynolds number, Re. It is also typically used within correlating parameters in more empirically-based methods. This can be seen in the two-phase pressure drop correlations given in Table A-6a through Table A-6e, Two-Phase Pressure Correlations. These types of equation formulated for two-phase viscosities are more varied than those developed for density (above), since the concept of a mixture viscosity is more difficult to comprehend. A typical formulation for mixture viscosity is shown in equation (6-32):

L= no-slip liquid holdup

L HL NO SLIP–,

sL

M--------= =

L

qL

AHL

-----------=

M LHL 1 HL– G+=


(6-32)

In dealing with two-phase flow, surface tension is another physical property which affects pressure drop. It is typically used as a correlating property in determining slip liquid holdup, as well as in determining the different flow regimes (described later).

In systems involving a wet hydrocarbon mixture, there will often be enough water present to form a separate, second liquid phase. A majority of the current, accredited industry-standard methods are available in PIPEPHASE. In each method only one liquid phase is considered to be present. Therefore, when two liquid phases actually exist, they are bulked together to form one liquid phase. The physical transport properties required by the pressure drop method for the bulk liquid are then calculated by weighting the relative amounts of each phase present. Liquid viscosity, density and surface tension are all calculated in this fashion. In equation (6-33), any of these properties can substituted for x:

(6-33)

where:

Other viscosity mixing rules, e.g., the API methods and the Woelflin procedure (for cases involving water-in-oil emulsions) are also available in PIPEPHASE.

Two-Phase Flow Pressure Drop

The formula for calculating the pressure drop for two-phase fluids in pipes is analogous to the equivalent single-phase flow version shown in equation (6-19), except that the friction factor and physical properties are replaced by their two-phase equivalents:

(6-34)

Note: The definitions of the mixture density (M) and mixture friction factor (fM) terms are specific to the correlation in which they are employed.

The pressure loss term in equation (6-34) includes a two-phase friction factor, fM. In the past, researchers have spent a majority of effort in developing predictive correlations for the two-phase friction factor, as well as the slip liquid holdup term.

Flow Regimes

x = liquid viscosity, density, or surface tension

VOLFR = volume fraction

subscripts HC and WAT refer to the hydrocarbon and aqueous phase respectively

M L

HLG

HG=

xL xHCVOLFRHC

xWATVOLFRWAT

+=

dPdL-------– g

gc-----M sin

fMMM2

2gcdi---------------------

MMdM

gcdL-------------------------+ +=


When two fluids with different physical properties flow together in the same pipe, there will be a wide range of possible flow regimes. A flow regime (or flow pattern) is essentially a description of the flow structure, or distribution of one fluid phase relative to the other. For example, for upward flow of air and water in an inclined pipe, the dominant flow regime is generally described as either mist flow or slug flow. Different inclinations of pipe, together with the direction of flow, both have a major effect on the actual flow regime. Several correlations have been developed specifically for one type of topology and flow direction (see A). The types of flow regime encountered include, but are not limited to, those shown in Figure 6-8. Depending on the researcher, categories of flow regime may be labeled differently.

Figure 6-8: Flow Regimes in Two-Phase Flow (using Beggs & Brill Terminology)

A flow regime map is generally included as a “front-end” to most modern two-phase pressure drop calculation methods. The Taitel-Dukler-Barnea map, for example, is a graphical representation of flow regime correlated against superficial gas and superficial liquid velocities. Once the respective superficial velocities are known (for example, calculated from equations (6-23a-b)), the flow regime can be easily read off the graph. Depending on which flow regime is suggested for those superficial velocities, a regime-specific correlation for liquid holdup is then invoked. It must be noted at this point that


different pressure drop correlations begin with a different flow map, since the link between resultant pressure drop and flow regime has typically been made by regression during the experimental phase of the research.

Note: The flow regime predicted by an individual pressure drop correlation may not reflect the actual regime encountered in reality, but the use of this regime in that particular correlation will produce the results as correlated and expected by the researchers.

One of the latest flow pattern predictions is the Taitel-Dukler-Barnea3 model. The Taitel-Dukler-Barnea flow map can be used as a good yardstick to determine which flow regime will actually prevail. The user can then utilize this map to design out undesirable topological components of a piping run which are found to instigate severe losses, or which produce mechanical and/or operational problems. Knowledge of the two-phase flow patterns and holdup behavior allow the engineer to make better decisions, whether mechanically retrofitting an existing system, or when developing a new design.

In the holdup and velocity detail report section of the output to PIPEPHASE, both the flow regime (FLOW REGM) as predicted by the pressure drop correlation, and the flow regime (T-D FLOW REGM) predicted by the Taitel-Dukler map are presented to the user for reference (PRINT DEVICE=FULL must be selected in the General Data Category of input).

Steps to determine flow Pattern using T-D method:

Operational Variables: Flow Rates qL and qg

Geometrical Variables: d, α

Physical Properties: ρL, ρg, μL, μg, σ

• Calculate equilibrium liquid level (holdup) from combined momentum equation

• Check transition A: stratified flow or non stratified flow

• If stratified, check transition C: smooth stratified or wavy stratified

• If non-stratified, check transition B or D

• Transition B: intermittent-annular transition

• Transition D: intermittent-bubble transition

The decision path is shown below:


Figure 6-9: Decision Path

Transition Criterion

Generalized T-D Flow Pattern Map


Figure 6-9a: Generalized T-D Flow Pattern Map

Single and Two-Phase Pressure Drop Correlations in PIPEPHASE

In PIPEPHASE the available pressure drop correlations for flow in circular pipes fall into four categories:

1. Single phase gas

2. Single phase liquid

3. Two-phase fluid

a) Standard correlations

b) Hybrid correlations

c) High velocity correlations

4. User-defined correlations

Categories (1) and (2) are relatively straightforward (see the discussion in the previous sections on single-phase fluid flow), and are generally based on the basic pressure drop equation (6-19).

Category (3) is divided into three types of correlation:


a) Standard correlations which have been incorporated directly into the PIPEP-HASE program from their published form.

b) So-called “hybrid correlations” which mix components of certain standard cor-relations to produce new correlations.The components that are taken from the standard correlations include the holdup method, the pressure drop components - friction, elevation and acceleration, and the flow map method. The mixes between components of standard correlations have been made such that the rele-vant transplants are consistent with the original correlation. This results in a wider choice of correlations from which a field data match may be found. In addition, more confidence may be gained in bracketing a solution value by the use of similar correlations. See Appendix A for a detailed breakdown of these hybrid correlations.

c) High velocity correlations, which have been developed as enhancements to stan-dard correlations. These correlations may be used to model high accelerational fluid systems where the standard correlations would normally break down.

Category (4) is a facility for users to implement their own pressure drop correlation(s) for pipes and/or for fittings. Further details on flow through fittings are given in later sections.

Critical Flow - A Qualitative Description

It can be shown that when a single-phase, compressible fluid flows in a pipe of constant diameter the velocity of the fluid cannot physically exceed the velocity of sound in the fluid medium. The term sonic velocity is used to describe the velocity of sound in the medium.

Critical or choked flow may be described by an example.

Consider a compressible fluid flowing in a horizontal pipe of uniform diameter and fixed inlet pressure. As the outlet pressure is gradually decreased, the flowrate will gradually increase. This trend will continue until the mass flux (i.e., velocity) reaches a maximum possible value at the outlet. Further lowering of the outlet pressure does not increase the flowrate. This flow condition is called critical, or choked flow. The outlet pressure at which critical flow is initiated is called the critical pressure.


Figure 6-10: Relationship Between Critical Velocity and Liquid Holdup

This phenomenon of critical flow is observed for single-phase gas as well as two-phase gas-liquid flow. For single-phase gas, the critical flow is reached when the velocity reaches sonic velocity. For multiphase flow situations, sonic velocity and critical flow velocity are not equal in magnitude.

A plot of critical velocity versus the liquid holdup generates an unusual U-shaped curve (see Figure 6-11). This indicates that the critical velocity for two-phase flow (HL > 0.0) may be much less than the critical velocity for gas only flow (HL = 0.0). The minimum critical velocity is reached at a liquid holdup value of approximately 0.5.

The Pressure Discontinuity

When the critical, or choked flow condition has been reached, further lowering of the outlet pressure does not increase the flowrate. In reality, a pressure (and temperature) discontinuity occurs at the outlet of the pipe. Referring to Figure 6-11, to the left of the discontinuity, the velocity is critical and the pressure is critical pressure. To the right of the discontinuity, the flow is subcritical and the pressure is set pressure, which is less than the critical pressure.

For flow in a pipe of uniform cross sectional area, a pressure discontinuity and critical flow can normally occur only at the outlet of the pipe. This implies that critical flow can potentially occur where the flow area changes to a higher value (such as expansions).

In reality, the pressure discontinuity manifests itself as a shock wave. Critical flow is therefore often accompanied by an intense rhythmic dissipation of energy and vibrations. A localized increase in the rate of heat transfer may also be observed.

Note: Currently, PIPEPHASE solves for critical flow in chokes only.


Figure 6-11: Pressure Discontinuity

Single-Phase Flow

Table 6-1 lists recommendations for the single-phase pressure drop correlations available in PIPEPHASE. The recommendations are provided to help the user choose the most appropriate correlation for a given application. For users who need more information, see A.

Note: The original Panhandle B and Weymouth correlations for gas flow were reformulated to separate the pressure losses due to friction, elevation, and acceleration. Equivalent friction factors were also derived.

Table 6-1: Recommendations for Single-Phase Pressure Drop Correlations

Correlation Recommendations

Gases

Panhandle B Good for long and/or large diameter pipes.

Weymouth Good for short and/or small diameter pipes.

Moody (default) Applicable for all diameters and lengths. Especially good for high velocity lines since acceleration losses are considered.

American Gas Association Recommended by the American Gas Association.

Liquids

Hazen-Williams Applicable for low viscosity fluids like water and gasoline. Should not be used for high viscosity fluids.

Moody (default) Applicable for fluids over a wide range of conditions.


Two-Phase Flow

The available two-phase empirical correlations for Horizontal and Inclined Flow are listed in Table A-2, Recommendations for Two-Phase Pressure Drop Correlations

Note: BBM correlation is recommended for all angles.

In addition, PIPEPHASE offers several hybrid correlations, see Table A-4, Hybrid Models Summary.

Note: Mukherjee-Brill correlation is recommended for inclined pipeline profiles especially for downward two-phase flow.

While the extensive selection of correlations available in PIPEPHASE offers a variety of methods for predicting two-phase fluid flow behavior, it also presents the typical user, who is not necessarily an expert in fluid flow methods, with a problem in selecting the appropriate correlation. Table A-2, Recommendations for Two-Phase Pressure Drop Correlations, presents a set of recommendations for selecting the appropriate correlation from the range of available choices.

Mechanistic Models

PIPEPHASE supports the following mechanistic two-phase flow correlations:

• The Ansari model for vertical flow

• The Xiao model for horizontal and near-horizontal flow

• The comprehensive TACITE hydrodynamic model, and

• The comprehensive OLGA hydrodynamic model.

Note: TACITE and OLGA are steady-state implementations of commercial transient codes.

A brief description for each of these methods is provided in the following sections.

Ansari

The Ansari77 method, developed at the Tulsa University Fluid Flow Projects (TUFFP) is a comprehensive mechanistic model for upward two-phase flow, covering each of the flow patterns encountered as well as the corresponding transitions.

The model first determines the existing flow pattern from the transition relationships. These transitional relationships are based primarily on the work of Taitel et al.78 and Barnea79.


When dispersed bubble flow is predicted, the flow characteristics are modeled on the basis of a homogeneous, no-slip model. At lower liquid velocities, the bubble flow model, based on an analysis of the bubble rise velocity, is an extension of the work by Caetano80. The slug flow model is characterized by a series of Taylor bubbles separated by liquid slugs. Separate models have been formulated for both developing and fully developed slug flow, depending on the nature of the Taylor bubble. The analysis is based on the work of Fernandes81, Caetano80, and Sylvester82. Annular flow is characterized by a liquid film surrounding a gas core, comprising of both gas and entrained liquid droplets. The annular flow model is based on Barnea’s analysis, originally developed for flow pattern prediction.

The acceleration component of the pressure drop has been ignored for all flow regime models.

Experimental validation of the Ansari model was achieved by comparing predictions against the data available for vertical wells in the TUFFP Databank. This included some of the recent data obtained from Arco’s operations in the Prudhoe Bay field in Alaska.

Xiao

Like the Ansari work, the Xiao83 model was also developed at TUFFP. It is a comprehensive mechanistic model developed for horizontal and near-horizontal pipelines. Flow pattern prediction, which forms the basis of the analysis, were based on the pioneering work of Taitel and Dukler84 and its subsequent extensions.

The Taitel and Dukler two-fluid formulation has been used as the basis for the stratified flow model. Interfacial shear has been addressed through a combination of the separate approaches by Andritsos and Hanratty85, and Baker et al.86 The treatment of the annular flow geometry, under the assumption that flow in the gas core is homogeneous, is similar to the two-fluid stratified flow model. The Oliemans et al.87 model, originally developed for vertical annular flow, was used to represent interfacial friction and liquid entrainment Intermittent flow was characterized by alternating liquid slugs and gas pockets, with a stratified layer flowing along the bottom of the pipe. The Taitel and Barnea88 approach was used to develop the fundamental slug flow model, with the Taitel and Dukler approach to shear stress modified for the specific flow geometry.

Field validation was based on the American Gas Association (AGA) database, as well as field data presented by Mcleod et al. A majority of the validation was based on comparison of model predictions against small-scale laboratory data.

TACITE

The TACITE hydrodynamic model is the steady-state basis for a comprehensive transient simulator. The details of the model are outlined in the work of Pauchon et al.89


TACITE, which is applicable for any pipe inclination, is based on the concept of characterizing any flow pattern as a combination of two basic geometries: separated and dispersed. Slug flow, for example, may be described as a combination of the stratified and dispersed flow patterns.

The bases for the formulation are the transport equations for multiphase flow. These include separate mass conservation equations for each of the two phases, and combined momentum and energy balances. The remaining equation, defining closure, is obtained from the prevailing flow pattern.

For dispersed flow, the closure equation is the drift flux relationship for the gas velocity as a function of the mixture velocity, where the bubble diameter is obtained by balancing the work of surface tension with turbulent dissipation.

For stratified flow, the pressure gradient term in the separate gas and liquid momentum balance equations are equated. The interfacial shear stress term is approximated from the law proposed by Andritsos and Hanratty.90

The intermittent flow regime is treated as a periodic structure of dispersed and separated flows. The slug velocity is determined from an extension to relationship proposed by Nicklin et al.,91 using Andreussi and Bendiksens92 void fraction model for the liquid slug.

Validation of TACITE is based on data collected from a variety of sources, including the Boussens databank, stratified flow data obtained by TUFFP, and data obtained from the MPE project of BHRG. It has also been validated with field data collected by ELF Aquitaine and TOTAL. Two of these applications have been for gas condensate lines (NE Frigg, Zuidvaal), while the third was an oil (black) and gas line (Alwyn). TACITE is presently being tested against the database developed by a consortium of oil companies and research organizations for the MIRANDA project.

OLGA

The OLGA model has been described by Bendiksen et al.93 The physical model, valid across the range of inclination angles, is based on separate conservation of mass relationships for the gas and liquid phases, as well as for the entrained liquid droplets. The additional equations in the formulation are momentum balances for each of the two phases, and a combined mixture energy balance.

As with any other mechanistic approach, the application of the conservation equations is flow pattern-dependent. In particular, the friction factor and wetted perimeter terms are based on the predicted geometry of the flow distribution. As such, the first step in the algorithm is the determination of the flow pattern, based on the local distribution of two-phase parameters.

OLGA has been compared with data from various experimental facilities, covering a wide range of pipe sizes, fluids, inclination angles and operating conditions. The bulk of


this data was obtained from experiments at the SINTEF Two-Phase Flow Laboratory in Norway. The model was also tested with good agreement against a number of oil field facilities.

Recommendations on Pressure Drop Correlations

For recommendations on Single-Phase Methods and Two-Phase and Compositional Methods, see A.

Solution Algorithms Used in PIPEPHASE

The Calculation Segment and Iteration Methodology

The Calculation Segment

PIPEPHASE works in segments to determine the pressure, temperature, holdup, and flow pattern distribution in all flow devices: pipe, tubing string or annulus. A segment is the smallest calculation increment of a larger length of pipe as shown in Figure 6-12. Segment-specific results can be seen in the detailed report for flow devices in the PIPEPHASE output file.

Separate segment sizes can be specified for all horizontal (pipe) and vertical (tubing, annulus) flow devices, either as segment length or the number of segments per device, through the General Data Category of input. These options should be considered prior to any simulation involving significant changes in fluid density. Almost all multiphase and single-phase gas applications, as well as single-phase liquid models with sharp thermal gradients fall under this classification.

For blackoil, condensate and single-phase systems, the segment length is defaulted to a value equal to the length of the flow device (i.e., no segmentation). For compositional or steam systems, a flow device may be internally divided, automatically by PIPEPHASE, into several compositional segments based on a maximum limit to the enthalpy change per segment.

Figure 6-12: The Calculation Segment

Note: In Figure 6-12, m represents the total mass flowrate of fluid.


A shorter segment size will increase the accuracy of the simulation at the expense of computation time. If you are unsure of an optimal segment size, the simulation should be run first with default segmenting. In subsequent runs, you should adjust segment sizes on the basis of the results of the prior simulations until the optimal point is identified.

Default Segment Calculation Procedure

Figure 6-13 outlines the segment calculation procedure for every pipe, tubing, and annulus for compositional or steam systems. The procedure for implementing the pressure drop equations for flow devices described in the section titled, An Introduction to Fluid Flow, is iterative, since average conditions of pressure and temperature are required to calculate the phase equilibria and physical properties that are required by the pressure drop and energy balance calculations. To achieve this, PIPEPHASE employs an inner loop for the convergence on pressure, and an outer loop for enthalpy convergence.

For blackoil or single-phase fluids where there are no enthalpy calculations, the segment calculation procedure reduces to a single iteration loop.


Figure 6-13: Default Segment Pressure and Temperature Calculation Procedure


The SHORTPIPE Segment Calculation Procedure

The user has the option of employing a different algorithm for the calculation segment, known as the SHORTPIPE method (Figure 6-14). This method is activated from the CALCULATION statement in the General Data Category of input. Instead of using an iterative procedure to find average temperature and pressure over a segment, this method uses the inlet conditions to the segment on which to base all property and flash calculations. This technique therefore avoids any iteration, and is much faster than the default method. The user should consider using the SHORTPIPE method in the following situations (with associated restrictions):

Simulations where pipe runs contain fluids undergoing small pressure changes relative to the node inlet pressure. In these cases, fluid properties do not change significantly over a segment, and the assumption of using inlet conditions is valid. Using the SHORTPIPE method under these conditions will reduce the execution time considerably.

1. In high velocity/accelerational systems such as flare simulations where link conver-gence has been encountered. In these cases, the reverse of case (1) is true, and fluid properties change significantly across a given segment. Therefore, in switching to the SHORTPIPE method, the user should increase the number of segments per pipe (i.e. reduce the segment size) to increase each SHORTPIPE calculation segment accuracy.

2. In large compositional systems. In these cases, using the default segment calculation method results in very long execution times. In these situations the SHORTPIPE method may be specified in order to reduce execution times, but the number of seg-ments per pipe should be generally increased to ensure accurate physical property and flash calculations across each segment.


Figure 6-14: SHORTPIPE Segment Calculation ProcedureSHORTPIPE Segment Calculation

Procedure


The Single Link Calculation Method

This method simulates the single link algorithm which is used for line sizing, nodal analysis, and other simulation models that focus on a single link in the system. There are two possible solution scenarios for this method as shown below.

Figure 6-15: Single Link Calculation Method Options


PIPEPHASE divides the pipe sections into segments as defined by the user in the input, and then uses a “marching” algorithm to achieve pressure drop and heat transfer results. The term “marching” is used to describe the step-by-step process by which PIPEPHASE solves calculation segments sequentially.

Scenario A:

This is the simplest request of the single link method, and is a straightforward once-only pass from source to sink.

Note: The flowrate in this scenario can be fixed at either the source or sink node.

Scenario B:

With the pressure drop fixed over the link, the single link procedure must iterate on flowrate until an outlet pressure is achieved which matches that specified by the user.

The Network Calculation Method

A typical network which can be solved using PIPEPHASE’s network solution algorithm is shown in Figure 6-16.

Figure 6-16: A Typical Network


Definition of a Network

A PIPEPHASE network is defined as a system of two or more links joined together. A link is defined as a connection between two nodes. A node can be a sink (where fluid leaves the system), a source (where fluid enters the system), or a junction (where two links join together).

The network solution algorithm can be used to solve any type of pipeline network, from complex, multiphase looped systems tosingle-phase gas transmission lines .

Internally, PIPEPHASE generates a set of material and pressure balance equations from the input data, and proceeds to solve these equations simultaneously using a Newton-Raphson scheme and a matrix solver. As will be seen in the following section, almost any combination of flow and pressure node conditions can be solved, which gives you tremendous flexibility in solving a wide variety of problems.

Pressure Balance Method

The methodology for determining the pressure and flow distribution in a pipeline network is based on a pressure balance (PBAL) solution algorithm.

From a network flow balance, the PBAL algorithm first identifies the set of starting link flows which is the minimum set of link flow rates that completely define the network flow distribution. Spur links, which are flowrate-specified isolated sections that do not affect the rest of the solution, are identified and solved, independently of the general network solution.

The primary variables for the solution matrix are the starting link flowrates and all unknown pressure values at source boundaries. Pressure imbalances are computed at all fixed pressure sink or junction node boundaries, as well as at nodes with two or more incoming flows.

Newton-Raphson iterations are employed to solve the non-linear equation set. The elements of the solution Jacobian can be determined from the partial derivative of the node pressures with respect to the incoming link flowrates and the corresponding upstream pressures.

Mass Balance Method

The mass balance (MBAL) solution method is used to provide PBAL with a good initial estimate of the flow and pressure distribution in the network. The algorithm is based on the principle that the sum of all flows into (and out of) all nodes in a network must equal zero. Mathematically, the sum of all junction flows can be expressed as non-linear functions of the nodal pressure and temperature distribution in the network. The MBAL algorithm solves the non-linear set of equations by decoupling the network temperature field from the pressure field. Newton-Raphson iterations are used to solve the non-linear set of equations for nodal pressures. The solution for the decoupled temperature field follows from the conservation of energy at the junction nodes.


How to Set up a Network Problem

There are some basic rules common to any type of simulation which are listed below along with the rules which must be followed in setting up a network problem in PIPEPHASE.

• Before the PIPEPHASE program is used, you should write down the objective of the simulation, i.e., list which answers you want from the program output. This step pro-vides a focus which saves time and effort in entering data into the program.

• The network that is to be simulated should then be translated into a network dia-gram, similar to the one shown in Figure 6-16. Here the diagram consists only of nodes (sources, junctions and sinks), links, and alphanumeric names for each node, which can be up to four characters. Importantly, the network diagram includes arrows on each link to denote assumed input flow direction, and also marks the loca-tion and label of major items of process equipment, if relevant.

• The number of nodes in the system should then be counted, and next to each node a pressure (P) and flowrate (Q) annotation should be added.

• In a direct analogy with Kirchoff’s Laws in electrical engineering theory, any net-work must be configured such that the total number of pressures (P’s) and flowrates (Q’s) that are fixed by the user must equal the number of nodes present in the sys-tem, or

(6-35)

To assist in setting up networks and to follow good simulation practice:

• Each boundary node should have one fixed value and one estimated value.

• At least one boundary node pressure must be fixed.

In Figure 6-16, there are 7 nodes, and hence the number of P’s and Q’s to be fixed must equal 7 (i.e., the total number of P = and Q = ). All other P’s and Q’s are to be calculated by the program. The P’s and Q’s to be calculated by PIPEPHASE must be given an estimated value, either by the user in the input data, or automatically allocated by the program itself (denoted by P = and Q = ). With this equality rule in mind, the user has full flexibility in which node P and Q values are to be fixed, and which are to be calculated. The flowrate, Q, at a junction is zero, and is therefore always a fixed value. This is because at steady state, the net flow at the junction point is given by:

(6-36)

Therefore,

P Q+ FIXED Nodes P Q+ TO BE CALCULATED = =

Qin Qout=


(6-37)

• You may then specify the details of the structure within the links. The devices appearing in each link should be ordered sequentially in the direction dictated by the FROM=/TO= statement (see 4), or, in the case of loop links, the expected direction of flow.

• Assuming all other categories of input are satisfied, you are then ready to run the simulation. When problems are encountered, a printed iteration history can assist in diagnosing which course of action to take to produce a solution. To do this, use the ITER keyword in the PRINT statement prior to executing the run.

There are several additional tips on the setting up of networks, and these are given in a later section on Converging Network Simulations.

Fluid Models Used in PIPEPHASE

PIPEPHASE allows you to choose between two different categories of fluid models:

• Non-Compositional fluid,

and

• Compositional fluid

All heat transfer and pressure drop calculations performed by the program use certain fluid physical properties. The accuracy of these fluid properties is therefore of primary importance in system modeling. This section of the technical reference will enable you to choose the most appropriate method(s) for fluid properties, and to be conversant with the program default methods as detailed in the main manual text.

Non-Compositional Fluid Models

There are five fluid types under this category:

• Single-phase gas

• Single-phase liquid

• Blackoil

• Condensate

• Steam

These fluid models predict bulk fluid properties from the gas or liquid gravities (or densities) alone, and thus are useful in systems where there is little information known concerning stream compositions.

Qnet 0=


Single-phase Gas

This fluid model is used when there is no liquid phase present throughout the simulation. The gas specific gravity is used to calculate required physical properties.

Gas Compressibility (z)

You have the choice between the Standing-Katz7 (default) and Hall-Yarborough7 (for wet or dry gases) correlations to calculate the gas compressibility (z-factor). Standing-Katz data were taken from experiments with natural gas only, and the resultant z-factor accuracies are strongly reliant on a precise specific gravity entry. Standing-Katz is also able to correct for the existence of contaminants such as nitrogen, carbon dioxide, or hydrogen sulfide. The Hall-Yarborough methods for dry and wet gases result from curve-fitting original Standing-Katz data, and are also able to correct for the existence of contaminants. Both methods correlate z-factor as a function of specific gravity, temperature and pressure.

Gas Density (G )

This is calculated from:

(6-38)

Gas Viscosity (G )

You have the choice between the Lee8 (default, shown below) and the Katz9 correlations. Both correlations calculate the gas viscosity as a function of specific gas gravity, temperature, and pressure. The Katz method uses experimental data in the range 40-400ºF and 1<Pr<20.

Lee (default)

(6-39)

(6-40)

(6-41)

where:

TA = Temperature in Rankine

GPMzRT----------=

G 0.0001K 0.0433XGPzT------

exp=

K9.4 0.02M+ TA

1.5

209 19M TA+ + ---------------------------------------------=

X 3.5 986TA--------- 0.01M+ +=


Gas Specific Heat Capacity (CpG)

Specific heat is calculated as a function of temperature (ºF) using the correlation:

(6-42)

where:

Single-Phase Liquid

The single liquid phase fluid model is used when there is no gas phase present throughout the simulation. The liquid specific gravity is used to calculate required physical properties. With the non-compositional single-phase fluid model the you are able to specify the liquid as water or hydrocarbon, and in doing so activate the relevant default physical property correlations.

Hydrocarbon Liquid Viscosity (l)

You have the choice between the TUFFP (Beggs/Robinson)10 (default, described below) and Beal-Standing/Chew-Conally11 correlations for hydrocarbon liquid viscosity calculations. The latter method is based on an API gravity of 60 or lower, and a temperature of 300ºF or lower. Also, PIPEPHASE sets a minimum viscosity of 0.2 cP and a maximum of 10,000 cP for the Beal-Standing/Chew-Conally method.

Beggs and Robinson Correlation

The TUFFP (Beggs/Robinson) correlation is based on gravities in the range 16 < API < 58, temperatures in the range 70 < T (ºF) < 295, and pressures in the range 0 < P (psig) < 5250.

When oil-water emulsions are formed, the viscosity is calculated from the Woelflin correlation for tight, medium, or loose emulsions (Figure 6-17), or from a user-specified curve of viscosity ratio versus water cut.

Standing Correlation

Beal had presented a graphical correlation to determine dead-oil viscosity. However, Standing was able to present Beal's correlation with a mathematical equation for dead-oil viscosity. The API gravity and temperature should be known. The pressure should be 1-atm and temperature expressed in R. Refer 6-2.

Glaso Correlation

This correlation has been found to be extremely accurate for the ranges it has been recommended to be used. Glaso had derived the empirical correlation using data from North Sea. Refer Table 6-2.

T = Temperature in ºF

CpG = Heat capacity in BTU/lb

CpG 0.39 0.00085 T 100– +=


Vazquez and Beggs

Vazquez gave a correlation that accounted for increase in viscosity of oil, at a pressure above bubble point. However, this correlation is applicable for some specific data ranges, also presented in the Table 6-2. This method is used as default in PIPEPHASE.

Note: Vazquez and Beggs correlation is not applicable for dead oil

Oil-water Viscosity (L)

API Procedure

Oil-water mixture viscosity may be determined from volumetric mixing, or by the following API Procedure 14B. Refer Table 6-2 for the correlation.

Woelflin's Correlation

William Woelflin presented data that could be used to estimate the viscosity of a brine-in-oil type of emulsion from a known clean-oil viscosity. He proposed that the emulsions produced by incremental addition of water and mechanical mixing, the viscosity of the resulting emulsion increases exponentially with the water-cut, up to a point where the viscosity drops sharply to a value close to that of the parent water. The point at which the viscosity drops sharply is the inversion point, marking the inversion of the emulsion. Refer Figure 6-17.

However, weakness of this approach lies in the following assumptions: The reference graph takes no account of the varying degrees of mixing in practice but assumes total emulsification of the oil-water mixture. This may lead to over-estimation of pressure loss in pipes.

It is inaccurate to assume that all oils have the same inversion water-cut. The error in equipment specification due to this assumption could be large, especially for water cuts close to the inversion point.


Figure 6-17: Emulsion Viscosity Ratio (Woelflin)

Table 6-2: Correlations to Calculate Oil Viscosity Name Correlation Notes

BEGGS &

ROBINSON70Used for Ranges:16 < API < 5870 < T (ºF) < 2950 < P (psig) < 5250

STANDING72 Where

and Temperature expressed in oR

Use for Pressure = 1 atm

GLASO71

Where

K = 3.141 X 1010

T = system temperature in oF

Considered as the most accurate correlation for dead-oil viscosity.Ranges

VAZQUEZ &

BEGGS73

Where

RangesPressure = 141 to 9515 psiaGas Solubility = 90.3 to 2,199 scf/stbViscosity = 0.117 to 148 cp Gas Specific Gravity = 0.511 to 1.351

Oil Gravity = 15.3 to 59.5 oAPI*Applicable unsaturated crude oils.

L 10x

1–=

X 103.0324 0.02023API–

T1.163

-----------------------------------------------=

od 0.32 1.8 107

API4.53

----------------------+

= 360T 260–--------------------------

a 100.43 8.33 API+

=

od KT 3.444– APIlog a=

a 10.313 Tlog 36.447–= 20.1 API 48.1 50 T 300

o obppb

-----

m

=

m 2.6p1.18710a=

a 3.9X10 5– p 5––=


Water Viscosity (w)

You have the choice between the Beal (default) and ASME12steam table methods.

Specific Heat Capacity (Cp)

The specific heat capacity is evaluated as a function of oil gravity (degree API) and temperature (degree F):

(6-43)

Blackoil (and Other Empirical Methods)

The blackoil model refers to a multiphase fluid model commonly used in industry. This model predicts fluid properties from the specific gravities of the produced gas and oil, and the corresponding volumetric phase ratio at reference conditions (gas-oil or gas-liquid ratio). The phase split at in situ conditions is determined from empirical correlations. The corresponding single-phase properties are then evaluated from their respective fluid models.

API PROCEDURE

For R > 1,

For R < 1,

Used for oil-water mixture.

Symbol Definition Units Subscript Definition

API gravity degrees API b bubble point

formation volume factor bbl/stb o oil

M molecular weight dimensionless od dead oil

P pressure psia sc standard conditions

scf/stb g gas

dimensionless

T temperature oR or oF

Name Correlation Notes

Rqo

qw------=

L 1 23+=

L 2 1 2.5R+ =

Cp BTU / lb 0.33 0.0022 API 0.00055 T++=


The blackoil model assumes that the liquid at stock tank (i.e., at reference conditions of pressure and temperature) remains in the liquid phase under all conditions. The separated gas (at stock tank conditions), however is assumed to exist both as free gas in the vapor phase, as well as dissolved gas in the liquid phase. This approximation is usually valid for a crude oil that is heavier than 45 degrees API.

Note: In PIPEPHASE, the reference conditions for pressure and temperature are 14.70 psia and 60 degrees Fahrenheit, respectively.

Solution Gas-Oil Ratio

The solution gas-oil ratio is the volume of dissolved gas, expressed at standard conditions, per unit volume of stock tank oil, at a given condition of pressure and temperature. This ratio increases with pressure until all of the gas dissolves at the bubble point pressure.

Table 6-3: Notes and References for SOLUTION GAS/OIL RATIO CORRELATIONSName Correlation Notes

LASATER69 For

,

Use for API > 15Use with VAZQUEZ FVFBased on blackoils from Canada, the Western and Mid-Continental US, and South AmericaExperimental accuracy was 7%

For yg, PIPEPHASE does a piecewise curve fit

STANDING72 For = ~ 1000

For P < 1000,

where

Use for API < 15

Based on California gas-crude systems

Experimental accuracy was 10%

Rs Rp

Rs

379.3 35 o sc,Mo

-----------------------------------------------yg

1 yg–---------------=

ygvs.Pg

T 460+ ---------------------data

Rs

g Px 1.20482

18 1.20482------------------------------=

Rs g xP

13.46------------- 0.93023

1.20482

=

x 100.0125API 0.000917– =


Solution Gas-Water Ratio

The solution gas-water ratio is the volume of dissolved gas, expressed at standard conditions, per unit volume of stock tank water, at a given condition of pressure and temperature.

PIPEPHASE uses the Culbertson and McKetta correlation for calculating the solution gas-water ratio. This correlation was developed for pure methane, which is the predominant component in natural gases. It also assumes that the bubble point pressure for the water is the same as that for the associated oil. In general, the accuracy of this prediction is within five percent for natural gases.

Oil Formation Volume Factor

The oil formation volume factor is the in situ volume of the oil phase, comprising both oil and dissolved gas, that is occupied by a unit volume of oil at stock tank conditions. The formation volume factor is influenced by the amount of dissolved gas as well as the compressibility of the oil. Below the bubble point pressure, the oil formation volume

VAZQUEZ73For ,

For ,

where

Newer and more general than the Lasater and Standing correlations



B formation volume factor bbl/stb o oil

g specific gravity (60 F/60F) dimensionless s solution

M molecular weight dimensionless p produced


R gas/oil ratio scf/stb g gas

SG specific gravity at 100 psig dimensionless

T temperature F

y gas mole fraction dimensionless


API 30

RsSG P

1.0937 1011.172A

27.64------------------------------------------------------=

API 30>

RsSG P

1.187 1010.393A

56.06----------------------------------------------------=

A APIT 460+

---------------------=


factor increases as more gas dissolves with increasing pressure. Above the bubble point pressure, the formation volume factor decreases with pressure due to compressibility effects.

Table 6-4: Notes and References for Oil Formation Volume Factor Correlations


VAZQUEZ73For ,

For ,

Where

For P > Pb, see oil compressibility (discussed under Blackoil Physical Properties).

Use for API> 15

STANDING72For ,

Where

For P > Pb, see oil compressibility (discussed under Blackoil Physical Properties).

Experimental accuracy was 5%



B formation volume factor bbl/stb o oil

g specific gravity (60 F/60F) dimensionless s solution

M molecular weight dimensionless p produced


R gas/oil ratio scf/stb g gas

SG specific gravity at 100 psig dimensionless

T temperature F

y gas mole fraction dimensionless

P Pb< and API 30

B0 1 4.67x104–

Rs 0.175Dx+ +=

104–

1.8106RsDx108––

P Pb< and API 30

B0 1 4.67x104–

Rs 0.11Dx+ +=

104–

0.1337RsDx108––

D T 60– APISG

------------------------------=

P Pb<

B0 0.972 0.000147F1.175

+=

F Rs

g0.5

osc----------- 1.25T+=


Water Formation Volume Factor

The water formation volume factor is the in situ volume of water occupied by a unit volume of water at stock tank conditions. Since the solubility of gas in the water is negligible when compared to oil, its effect on the water formation volume factor is ignored in PIPEPHASE. Water formation volume factors are computed from water densities, using the 1967 ASTM formulations.

Surface Tension

Surface tension is an important parameter in flow pattern prediction. Oil surface tension is computed as a function of oil and gas gravity as well as pressure and temperature from the empirical work of Baker and Swerdloff. Gas-water surface tension is calculated as a function of pressure and temperature, using the method proposed for Katz et al for methane. The overall gas-liquid surface tension is obtained from volumetric averaging.

Fluid Mixing Rules for Blackoil Models

Fluid mixing occurs when two (or more) links having fluid coming into one node. Consider the following case in the below figure:

Gathering Network System


Fluid flows from sources A1, A2, and A3 to junction node A. Then, the combined fluid flows through link A-B.

Assume that the sources are associated with different PVT data sets to represent their fluid properties. What set of PVT properties are we going to use to calculate pressure drop or heat transfer in link A-B?

The combined (or composite) GHV value is calculated as follows:

GHVc = (QgA1 * GHVA1 + QgA2 * GHVA2 + QgA3*GHVA3)/ (QgA1 + QgA2 + QgA3)

where:

GHVc: Combined Gross Heating Value to be used in Link A-B

QgA1: Volumetric Gas Flow Rate at Standard Conditions in Source Node A1

GHVA1: Gross Heating Value for Fluid Coming from Source Node A1





Fluid properties like Oil Gravity, Gas Gravity, and Water Gravity for link A-B are also calculated as an average weighted volumetric average:

For Oil Gravity:

API c = (QoA1 * APIA1 + QoA2 * APIA2 + QoA3*APIA3)/ (QoA1 + QoA2 + QoA3)

where:

API c: Combined Oil Gravity to be used in Link A-B

QoA1: Volumetric Oil Flow Rate at Standard Conditions in Source Node A1

APIA1: Oil Gravity for Fluid Coming from Source Node A1


Node GHV (BTU/SCF)

A1 1200

A2 1100

A3 1250





Condensate

PIPEPHASE simulates gas condensate systems using the API Procedure 14B model. For these systems, gas may or may not condense depending on the in situ pressure and temperature. This model assumes no liquid is present below the dew point pressure. In situ condensate flowrate is calculated by multiplying the standard volumetric flowrate by a pseudoformation volume factor (pseudo-FVF).

The pseudo-FVF is the ratio of in situ condensate mass to the mass of condensate at stock tank conditions. The model assumes the condensate density is constant and equal to the density at stock tank conditions. (Since densities are assumed constant, the definition is based on mass.) The pseudo-FVF is a function of condensate specific gravity, dew point pressure, pressure, and temperature.

Dew point pressure, mass phase split (mass distribution between the liquid and vapor phases), and surface tensions of condensate and water are calculated from empirical relationships. Dew point pressure is a function of condensate specific gravity and temperature.

Note: Mixing methods are the same as blackoil.

Steam Model

Although the methods used are actually compositional, the steam fluid model is listed in this category because its use is activated by a statement which does not fall under the compositional fluid model category. This model involves a pressure-enthalpy formulation in order to calculate a pressure and temperature traverse. For water systems modeled with the steam method, PIPEPHASE uses the methods given in Table 6-5 for calculating fluid properties:

Table 6-5: Steam Property Calculation MethodsProperty Method

Steam quality and enthalpy SimSci steam package53

Steam viscosity SimSci component library

Water enthalpy SimSci steam package

Water viscosity Bingham & Jackson data32

Steam and water densities ASME steam tables (1967)


Compositional Fluid Models

Compositional Fluid Modeling is a method for describing a flow stream based on its pure and other pseudocomponents. Equilibrium phase splits and homogeneous phase properties are determined by blending the properties of the stream constituents.

Accuracy of Compositional Modeling

The accuracy of a compositional fluid model depends on the accuracy of the pure component properties, the accuracy and applicability of the thermodynamic property (phase split, enthalpy, density) generator selected, and the accuracy of the mixing correlations used in stream transport property calculations.

The compositional fluid model in PIPEPHASE is based on stream composition data input by the user. Pure component properties are taken directly from the PIPEPHASE component data library (Appendix A). For petroleum (pseudo-) components, the equivalent “pure properties” are calculated using industry standard characterization methods based on gravity, normal boiling point, and molecular weight.

Properties Calculated Using the Compositional Fluid Model

The following properties are determined for each component:

• Equilibrium K-values (phase split)

• Gas and liquid enthalpies

• Gas and liquid densities

• Gas and liquid viscosities

• Surface tension

• Gas and liquid thermal conductivities

Equilibrium K-Values (Phase Split)

Equilibrium K-values are used to predict the phase split for a given composition, pressure, and temperature.

Table 7-2 lists notes and references for the K-value methods currently available in PIPEPHASE. The references indicated in this table are given in C. These correlations were developed for, and are applicable primarily to hydrocarbon systems. Some of the equation-of-state methods require component properties such as critical temperature, critical pressure, and acentric factor. For pure components this information is available in PIPEPHASE’s data libraries, but for pseudocomponents this information must be predicted empirically. The methods so used and available in PIPEPHASE are given below:

• Cavett Method54 – default method, widely used in industry


• Cav80 Method55 – same as Cavett, but uses 1980 API Technical Data Book method

• Lee-Kesler23

• Twu56

Table 6-6: Notes and References for Equilibrium K-value Correlations for Compositional FluidsCorrelation Equation of State Notes

Soave-Redlich-Kwong27 Soave-Redlich-Kwong • Gives reasonable results for a wide range of conditions including cryogenic temperatures and pressures up to 5000 psia.

• Correctly predicts the homogeneous (dense) phase.

• Predicts phase behavior in the critical region. However, calculations become unstable at the critical point.

• Results for hydrogen-aromatic systems may be poor.

Peng-Robinson22 Peng-Robinson • Notes listed under Soave-Redlich-Kwong also apply to Peng-Robinson.

Lee-Kesler-Plocker23 Modified • Mixing rules handle mixtures of asymmetric molecules better than Benedict-Webb-Rubin mixing rules.

• Inaccurate near the critical point. Do not use for Tr > 0.96.

Benedict-Webb-Rubin-Starling-Twu29

Benedict-Webb-Rubin-Starling-Twu

• Generates data for a full range of fluids including light gases, synthetic fuel, and coal tar.

• Incorporates Starling’s binary interaction data modified by Twu.

Chao-Seader31 Hildebrand equation for liquid activity coefficients, Redlich Kwong equation for vapor fugacity

• Valid ranges: 0-500 F (-20-250C); <1500 psia (10,000 kPa)

• For hydrocarbons except methane, valid for 0.5 < Tr < 1.3.

• Should not be used when the concentration of H2 and CH4 in the liquid phase exceeds 20% of the other dissolved gases.

• Uses special coefficients for N2, H2S, and CO2 developed from data with < 5% CO2 or H2S at < 400 F (200 C) and < 1000 psia (7000 kPa).

• Not recommended for fluids with > 5 mol% CO2 or H2S.


Enthalpy

The energy balance part of the iterative calculation segment solution procedure is based on fluid enthalpy. Fluid enthalpies are calculated (except for the Johnson-Grayson correlation) from the relationship:

(6-44)

where

Table 6-7 lists notes and references for the enthalpy correlations currently available in PIPEPHASE.

Table 6-7: Notes and References for Enthalpy Correlations for Compositional Fluids

Grayson-Streed32 • Valid ranges: 0–800 F (-20–450 C); < 3000 psia (20,000 kPa).

• Extension of Chao-Seader.• Often used for hydrogen-rich systems

and heavy ends.• Has been extrapolated to 1000 F

(550 C) with good results.

Braun K1033 • Valid ranges: > 100 F (40 C); < 100 psia (700 kPa).

• Good for low pressures only.• Good for heavy ends.• Results found reasonable up to 1200 F

(650 C).

H = Enthalpy

H* = Ideal gas enthalpy of the mixture

H = Enthalpy deviation for the mixture

Correlation Notes

Soave-Redlich-Kwong27 • Comparisons with experimental values show an average deviation of 1 Btu/lb.

• Produces reasonable results for non-hydrocarbons when Tc, Pc and are known.

Peng-Robinson22 • Essentially the same as the Soave-Redlich-Kwong correlation except uses the Peng-Robinson equation of state.

• See notes listed above for Soave-Redlich-Kwong.

Correlation Equation of State Notes

H H* H– H* RT z 1– TPdTd

------

vP– Vd

V

+ += =


Heat Transfer in Flow Devices

The effect of heat transfer in flow devices can significantly alter the overall accuracy of the simulation. The addition or removal of a small amount of heat to or from a system may alter the physical properties of the fluid enough to cause a significant change in the pressure drop across a device. Therefore, in certain systems, the accurate simulation of heat transfer is important for the reliable prediction of pressure drop.

The heat transfer to a flow device is calculated in two ways depending on whether the fluid model is non-compositional or compositional.

Note: See The Calculation Segment, p. 6-27, for a discussion of the calculation segment, and Enthalpy, p. 6-50 for the logic for enthalpy balancing

Lee-Kesler25 • Recommended by the API Technical Data Book. • Results good for a wide variety of hydrocarbon mixtures.• Covers a wide range of reduced pressure and temperature.• Gives reasonable results for slightly polar chemical mixtures.• Uses a three-parameter corresponding states principle.• Developed from two equations of state similar to the Benedict-Webb-

Rubin equations.

Lee-Kesler-Plocker23 • Modification of the Lee-Kesler correlation.• See notes listed above for Lee-Kesler.

Benedict-Webb-Rubin-Starling-Twu29

• Computes deviations from ideal gas enthalpies.

Curl-Pitzer19 • Good for Pr < 10, 0.35 < Tr < C 4.0 for liquids, 0.6 < Tr < 4.0 for gases.

• Limited to non-polar mixtures.• Predicts both liquid and gas enthalpies.• Relates deviation from ideal gas enthalpy to Tr , Pr , and for the

mixture.• Uses the mole average acentric factor and calculates mixture Tc and Pc

from mixing rules by Stewart, Burkhart, and Voo.

Johnson-Grayson46 • Essentially an ideal enthalpy correlation for petroleum fractions. • Useful for heavy ends between 0 and 1200 F (-20–650 C). May be

extrapolated to higher temperatures.• Should not be used for C4–C5 or lighter mixtures.• Calculates gas phase corrections using the Curl-Pitzer equation.

Correlation Notes


Heat Transfer for Non-Compositional Fluids

For non-compositionally (empirically) defined fluids, PIPEPHASE assumes that the heat transferred from the fluid to its surroundings is equal to the heat change in the fluid itself. In differential form, the heat transferred from the fluid to the surroundings is given by:

(6-45)

where:

The change in the fluid temperature due to heat transfer from the fluid is given in differential form as:

(6-46)

where:

In order to calculate the fluid temperature changes, equations (6-45) and (6-46) are set equal, and integrated over the segment length L.

A special numerical integration yields an approach to an exponential curve, where the fluid temperature approaches the ambient temperature.

Heat Transfer for Compositional Fluids

Heat transfer for compositionally-defined fluids or PIPEPHASE’s steam fluid model is calculated using an enthalpy balance. Over each calculation segment, a change in enthalpy may result from a change in fluid kinetic energy, a change in fluid potential energy, or energy lost to or gained from the surrounding medium. This enthalpy balance is given by equation (6-47).

(6-47)

dq = rate of heat transfer from the fluid to the surroundings

U = overall heat transfer coefficient

T = temperature difference between fluid and the surroundings

dA = area through which heat flows and on which U is based = d dL

d = diameter

L = length

= rate of heat change in the fluid ( denotes difference with Eqn. (6-45))

m = mass flowrate

Cp = specific heat capacity of the fluid

= differential change in fluid temperature ( denotes difference with Eqn. (6-45))

dq UTdA=

dq· mCpdT·=

dq·

dT·

H HKE HPE Qout+ +=


where:

Equation (6-47) can be further expressed as:

(6-48)

where:

Figure 6-18: Heat Transfer for Compositional Fluid Models and Steam

Figure 6-18 (a) represents the analytical solution of equation (6-48). This would be the result if PIPEPHASE were able to compute an infinite number of segments. Instead, PIPEPHASE uses numerical integration techniques. Therefore, as shown in Figure 6-18 (b) and (c), the approach to reality (Figure 6-18 (a)) becomes closer with the more calculation segments you specify.

H = Overall change in enthalpy

HKE = Change in enthalpy due to kinetic energy

HPE = Change in enthalpy due to potential energy

Qout = Energy change with surrounding medium

P = Estimated change in pressure over the segment (psia)

P = Average pressure in the segment (psia)

z = Vertical elevation change over the segment (ft)

L = Length of the segment (ft)

d = Reference diameter on which U is based (usually di or do)

Tavg = Estimated average temperature in the segment (ºF)

TG = Ambient Temperature at the middle of the segment (ºF) = TGa - (Tgrad)(z)

TGa = ambient temperature at the middle of the previous segment (ºF)

Tgrad = Temperature gradient (ºF per ft. elevation)

vm = Mixture velocity

vsG = Superficial gas velocity

HmsGP–

778 3217 P----------------------------------- z

778 -------------

Ud Tavg TG– L

3600 m ------------------------------------------------–+=


The Overall Heat Transfer Coefficient (U-value)

For pipes in PIPEPHASE, the U-value defaults to a value of 1.0 BTU/hr-ft2-ºF unless you specify otherwise in the input. PIPEPHASE is able to rigorously calculate the U-value and also allows you to override individual heat transfer coefficients, if desired.

Figure 6-19 shows a cross-section of a pipe, including each “layer” through which heat must pass to be transferred from the fluid to the surroundings, or vice-versa. These layers have an overall resistance comprised of the sum of the resistances of the individual layers.

Figure 6-19: Pipe Heat Transfer Resistances

The U-value for a pipe is calculated from:

(6-49)

The overall resistance is given by:

(6-50)

where:

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 or user-defined)

Rinside = An additional resistance inside the pipe (optional)

U 1

Resis cestan

--------------------------------------=

Resis cestan Rinside film, Rpipe Rinsulation Rsurr Rinside Routside Rrad+ + + + + +=


Equations used in PIPEPHASE to Calculate Resistances

Inside film resistance

(6-51)

where:

The Reynolds number is given by equation (56):

(6-52)

Pipe resistance

(6-53)

where:

Insulation resistance

(6-54)

where:

Routside = An additional resistance outside the pipe (optional)

Rrad = Radiation (optional)

d = pipe inside diameter

kf = thermal conductivity of the film

Re = Reynolds number

di = pipe inside diameter

do = pipe outside diameter

kp = thermal conductivity of pipe

subscript j refers to the Jth layer of insulation (1J 5), and as applied to the diameter, d, subscript J refers to the outer diameter of the Jth layer, and J-1 refers to the inside diameter of the Jth layer.

Rinside film,d

0.27kfRe0.8

----------------------------=

ReLL GG+ L G+ di 124.016

LL GG+--------------------------------------------------------------------------------------------------=

Rpipe

dloge do di 24kp

---------------------------------=

Rinsulation1

24------ d

1kj----loge

dj

dj 1–-----------

j 1=

n

=


Buried surroundings (e.g., soil resistance)

(6-55)

where:

Fluid surroundings (e.g., air, water)

(6-56)

The Reynolds number in equation (6-56) is given by:

(6-57)

Additional inside/outside resistance

(6-58)

(6-59)

where:

Note: You can supply the inside and outside heat transfer coefficients by using the HINSIDE and HOUTSIDE keywords.

Radiation film resistance

(6-60)

D = depth from top of soil to pipe center line

Dt = diameter of pipe plus insulation

ksurr = thermal conductivity of surroundings

Hinside = Additional inside heat transfer coefficient (BTU/hr-ft2-ºF)

Houtside = Additional outside heat transfer coefficient (BTU/hr-ft2-ºF)

Rsurr

dloge 2D 4D2

Dt2

– 0.5

+ Dt

24ksurr-----------------------------------------------------------------------------------=

Rsurr

do

12ksurr10 Resurr 1.3681log Pr0.333

--------------------------------------------------------------------------------------------=

Resurr

181.89surrsurrDt

surr------------------------------------------------=

Rinside 1 Hinside=

Routside 1 Houtside=

Rrad 1 Hrad=


where:

Note: You can supply the radiative heat transfer coefficient by using the HRAD keyword.

The additional inside resistance (Rinside) is added to the Inside Film Resistance (Rinside, film) and the additional outside heat resistance, (Routside) is added to the fluid surroundings resistance or buried surrounding resistance, (Rsurr).

If the radiation film resistance (Rrad) is available, then this contribution is not added to (Rsurr + Routside) but rather treated as a parallel contributor in the following way:

(Rsurr + Routside)*Rrad/ (Rsurr + Routside + Rrad) (6-61)

Partially Buried Pipes

It is possible for pipes to transfer heat to two different media (air and soil, for example) simultaneously. To achieve this, PIPEPHASE allows negative values for the keyword BDTOP. For example, values of BDTOP < 0 and |BDTOP| < OD indicates a partially buried pipe.

For this situation, the program calculates two different values for the heat-transfer coefficient: one for the buried portion and the other for the exposed portion. Then, an area-weighted equivalent value is calculated to represent the outside heat-transfer coefficient. The calculations do not take into consideration any variation in the wall temperature between these two portions of the pipe.

Heat Transfer in Wellbores95

Heat transfer in the wellbore is of particular importance in the simulation of hot fluid

Heat losses in the wellbore never reach a steady state. They attain a quasi-steady state in which the rate of heat loss is a monotonic decreasing function of time, dependent on the rate at which heat is lost to the formation. The time-dependent term in the overall heat transfer coefficient which reflects the thermal resistance95 of the formation as defined by Ramey has been included in PIPEPHASE.

Additional PIPEPHASE capability in this area includes the ability to simulate heat transfer effects in concentric and parallel tubing strings

Laminar Flow Heat Transfer

Laminar flow conditions typically exist in situations where viscous fluids are being transported. The need for the accurate prediction of heat transfer effects becomes critical on account of the temperature dependency of viscosity under such conditions. PIPEPHASE uses Churchill’s approach for determining the heat transfer coefficient for

Hrad = Radiative heat transfer coefficient (BTU/hr-ft2 ºF)


both the laminar and transition regimes. Note that the friction factor derived from this method is used solely for the purpose of calculating the heat transfer coefficient and does not affect the hydraulic calculations in PIPEPHASE.

Equipment & Fittings Flow Devices

In addition to modeling pipes, PIPEPHASE also enables you to model items of process equipment and pipe fittings inside links. These items are viewed as flow devices, and are therefore treated in an analogous fashion to the pipe device available in the program. The accurate modeling of process equipment, such as heaters, coolers and pumps, is especially important in systems where pressure changes are largely due to these items, rather than the piping runs.

The calculations associated with the equipment flow devices given in Table 6-8 are discussed in this section.

Note: PIPEPHASE does not consider any length or elevation pressure drop effects within these equipment types.

Table 6-8: Equipment Devices Modeled by PIPEPHASE

A discussion of the available fittings devices is presented later in this section.

Pump

The pump device should only be used for incompressible fluids. If the fluid is compressible then the compressor unit should be used instead.

PIPEPHASE uses the standard GPSA pump equation to relate power and pressure increase:

(6-62)

where:

Pump Compressor

DPDT device Choke

Check Valve Heaters and Coolers

Separators

Qv the volumetric flowrate (gpm)

the percentage pump efficiency

In equation (6-62), power is measured in horsepower, hp.

PowerQP

1715---------------=


Lost work (through pump inefficiency) is converted to heat, which may cause the fluid temperature to rise. The resulting fluid temperature is given by equation (6-63).

(6-63)

where:

Electrical Submersible Pump (ESP)

The ESP model in PIPEPHASE is an extension of the basic pump model. ESPs are a common method of artificial lift applicable to wells producing at rates ranging from a few hundred barrels to thousands of barrels per day. The application of ESPs is limited by excessive free gas and high temperatures associated with deep wells.

In addition to the head and efficiency curves required for the standard pump model in PIPEPHASE, the performance of an ESP is characterized by a horsepower curve, defined as a function of the flowrate. The effect of viscous fluids is modeled through the Riling correction factor to the performance curves. PIPEPHASE also supports user-specified data on the effect of free gas on pump performance.

In order to reduce the gas injection rate, ESPs are sometimes configured with upstream separators. PIPEPHASE will allow you to specify the gas injection percentage into the pump based on this separator. The separated gas may be reinjected back into the production stream or vented to the atmosphere.

Compressor

PIPEPHASE uses the standard GPSA equation to relate compressor power and outlet pressure:

(6-64)

where:

the specific gravity of the fluid

T = the temperature in degrees Rankine (R)

Cp = the fluid specific heat capacity at constant pressure, and for compositional fluids is equal to dH/dT, which is computed rigorously through flash calculations.

Subscripts inlet and outlet refer to the pump inlet and outlet conditions respectively.

zavg = the compressibility at average temperature and pressure

adia the adiabatic compressor efficiency

Toutlet

Tinlet2.31P

---------------- 1

1–---------- +

780CP--------------------------------------------------------------=

Power

1545mzavgTinlet P2 P1

k 1–k

-----------

1–

550Madia k 1– k ---------------------------------------------------------------------------------------=


Lost work (through inefficiency) is assumed to be converted to heat which may cause the temperature of the fluid to rise:

(6-65)

DPDT Devices

DPDT devices simulate equipment for which no standard PIPEPHASE model exists. These devices are typically used to model the performance of specially designed valves and fittings. For these devices, you supply data relating the fluid flowrate, the pressure change and temperature change in tabular form.

PIPEPHASE linearly interpolates this table during calculations, and therefore you should ensure that data entered covers the whole range of anticipated equipment process conditions. If the entered range of data is exceeded at any point in during the simulation, PIPEPHASE uses the last tabular data point. Therefore if you are unsure as to the likely simulation range, then a dummy high or low value should be entered in this device in order that a reasonable value is selected by PIPEPHASE in any possible simulation condition.

Chokes

The fluid model type you have chosen dictates which correlations are used for calculating the pressure drop across a choke.

Single-Phase Gas and Single-Phase Liquid Models

For these fluid models, the choke pressure drop is calculated from equations (6-66–6-70) based on a square-edged orifice (shown in Figure 6-20).

Cr = fluid specific heat capacity and constant volume

m = mass flowrate

M = average molecular weight of fluid

P2 = outlet pressure

P1 = inlet pressure

Toutlet Tinlet

Tinlet P2 P1

k 1–k

-----------

1–

adia---------------------------------------------------+=


Figure 6-20: Choke Model in PIPEPHASE — Schematic

(6-66)

(6-67)

(6-68)

(6-69)

(6-70)

where:

If a discharge coefficient of zero is input, PIPEPHASEwill calculate the coefficient from the diameter ratio, , and the Reynolds number.

k = Specific heat ratio, Cp/Cv

Y = Gas expansion factor for nozzles

Ddis = Orifice discharge coefficient

P P1 P2–=

P1

oo 96.26YC 2

1---------------------------------------------=

P2

oo

2

64.4-----------

222

64.4-----------–

o–o

2

64.4---------- 1 2

– 2

144

Y 1 0.41 0.354+ 1 k 1 Po P1– –=

----------------------------------------------------------------------------------------------------------=

C Ddis 1 4–

0.5=

d0 d1=


Gilbert Family (GF) of choke models

The Gilbert family (GF) (Gilbert, Ros, Baxendell, Achong) are 'critical flow only' choke models. They do not model sub-critical flow. For critical flow, the flow rate through a choke is a linear function of inlet pressure, the other parameters in the model (ID,GLR) being constant.

These choke models therefore do not predict choke outlet pressure and should not be applied if flow is subcritical. This makes the model incomplete to be a standard/classic PIPEPHASE device feature. To get around this problem and make the model sufficiently complete in a consistent way, we have the following implementation:

a) Use of the Gilbert Family (GF) of choke models implies critical flow is assumed at the choke. PIPEPHASE will determine what the critical flow would be (for algorithm see below). For critical flow to physically occur the outlet pressure needs to be equal or below Pcrit. Pcrit is the choke outlet pressure at the onset of critical flow. Further lowering of the outlet pressure will not increase the flow rate.

b) The user can nominate a critical pressure ratio Rcrit (=Poutlet/Pinlet) which occurs at the onset of critical flow. PIPEPHASE output will notify if the calcu-lated pressure ratio is not consistent. If Rc<= Rcrit the results are consistent oth-erwise the GF choke models are inappropriate. The default Rcrit is set at 0.55.

c) The onus is on the user then, to determine what he should do about the choke model selection.

Algorithm:

The GF choke models are represented by:

(6-71)

Where:

A,B,C are constants. The standard values of these constants are as follows:

P1 = Inlet pressure (psia for Ros and psig for others)

ql = Liquid flow rate (stb/day)

Rp = Producing Gas-Liquid Ratio Scf/stb

d Diameter of the choke in 64ths of an inch

PlAqlRp

B

dC-----------------=


Table 6-9: GF Model Constants:

Network Solving Algorithm with a GF Choke in Source Link(s)

1. Before the network algorithm begins, check for GF chokes in source links(only). For each of these links there are 3 possible conditions:

a) Source Pressure is fixed flow rate, Q is estimated

b) Source Q is fixed and P is estimated

c) Source P and Q are fixed

2. If (a) then calculates intersection of the choke performance curve and the well per-formance curve (for devices before the choke) to determine the critical flow rate. Pass the critical flow rate as the source flow rate for the network. From a network set up point of view this 'source pressure specified' boundary condition is now replaced by a source Q specified BC. Ensure that at-least one pressure of the new network is set, to ensure the well-posedness of the network problem. If well-posedness is vio-lated then the program will fail to solve the problem.

3. If (b) determine required choke upstream pressure(usually well head pressure) from the choke model. Then calculate required source pressure to satisfy the calculated wellhead pressure and flow rate. Pass the critical flow rate as the flow rate to the net-work model. No BC alteration is necessary.

4. If (c) then simply calculate the choke upstream pressure and resize the choke diame-ter. Pass the set flow rate as the network source flow rate.

5. These ‘GF source links’ are then modified so that link calculations start at the first device after the choke and the BC is changed if necessary so that flow rates are specified and pressure is estimated.

6. Solve the modified network.

7. Make a final network run using the original link devices which by default will use previously calculated choke outlet pressure for output. Check for pressure ratio con-sistency and generate appropriate output message if CPR rule (see above) is vio-lated.

Network Solving Algorithm with a GF Choke in Internal and Sink Link(s)

If more than one GF choke is specified in the source link or if GF chokes are present in any internal links or sink links the choke calculations for these chokes will be simplified. The CPR will simply be used to calculate the outlet pressure. The choke diameter will

GF Model A B C

Gilbert 10.0 0.546 1.89

Ros 17.4 0.500 2.00

Baxendell 9.56 0.546 1.93

Achong 3.82 0.650 1.88


have no effect. Essentially the GF choke will simply act as a device which causes a pressure drop based on the specified CPR. It is recommended that multiple GF chokes in source links and GF chokes in internal links and sink links not be used unless the user wants the intended effect as described.

Extensions of the GF Model Applicability

The GF chokes are classically applicable for blackoil systems (with GLR >0) only over a reasonable range of GLR's. See equation 6-71.

To provide more flexibility to the user, PIPEPHASE has consistently extended the GF choke concept to other fluid models which are 2-phase(vapor-liquid) at standard conditions for compositional and condensate (LGR>0) fluid models. The user needs to exercise care when applying it for cases where the standard GLR for these fluids fall beyond the applicable range. It would behoove the user to first match field data to the above model and correlate the values of A, B and C coefficients before modeling the chokes in PIPEPHASE.

The model has been further extended (to give additional user flexibility) for single phase fluid models LIQUID and GAS. If any fluid model predicts single phase liquid at standard conditions, the program arbitrarily sets the value of Rp to 1 in equation (6-71). If any fluid model predicts single phase vapor at standard conditions, the program uses the following equation:

(6-72)

Qg is the standard gas flow rate in mscf/day.

Other variables are the same as described above.

It would behoove the user to first match field data to the gas or liquid models and correlate the values of A and C coefficients (B being not applicable) before modeling the chokes in PIPEPHASE.

The GF choke models are not allowed for steam models.

Greater care should be used by the user in using these models for fluid models other than Blackoil. It is recommended that the user incorporate/regress choke flow measured field data to arrive at the proper values of A, B, C.

Errors and Warnings

If the network CAlculated Pressure Ratio (CAPR) is greater than the user specified CPR then a warning message indicating the choke may be in subcritical flow will be printed out.

PlAQg

dC----------=


Other Fluid Models

For these fluid models, PIPEPHASE calculates the choke pressure drop from the correlations developed for multiphase fluids. The Fortunati method57 involves two steps:

• A Fortunati curve is interpolated to determine whether the flow is subcritical or crit-ical.

• In the case of subcritical flow, the Fortunati curve is used to determine an outlet-to-inlet pressure ratio. From this ratio, the upstream or downstream pressure is calcu-lated. In the case of predicted critical flow, the critical pressure ratio is used to calcu-late the outlet pressure which is the maximum outlet pressure possible to allow critical flow.

See References (96, 97) for additional information on the Perkins and Ueda choke models.

Check Valves

Check valves are used to permit flow in one direction only. To effect this, the valve closes to prevent backflow. In PIPEPHASE, these actions are similarly simulated and the relevant pressure drop calculations use the square-edged orifice equations as per the choke device implementation. If the flow is determined to be multiphase, PIPEPHASE uses the same square-edged orifice equations, but assumes the fluid is a uniform mixture.

Heaters and Coolers

The fluid model type you have chosen dictates which correlations are used to relate the heater or cooler duty to the fluid temperature change.

Single-Phase Gas and Single-Phase Liquid Models

(6-73)

Compositional and Steam Fluid Models

(6-74)

The pressure drop across the heater or cooler device can be modeled either by:

• Specifying the value directly

or

• Defining the coefficient and exponential term in the relationship:

(6-75)

Q mCpT=

Q mH=

P=coeff .(rate)exp


where the rate is always expressed in units of pounds per second (lb/sec).

Separators

The phase split at separator conditions is determined from the fluid model equilibrium calculations. The separator model then removes a user-specified percentage volume or volumetric rate of fluid from a phase or phases.

Blackoil

The phase split is determined using the blackoil empirical correlations. Only gas may be removed from the system.

Condensate

The phase split is determined from the condensate model equilibrium calculations. Condensate and/or water may be removed from the system.

Compositional

The phase split is determined by a flash at separator pressure and temperature. Fluid may be removed from any stream: gas, oil, and/or water.

Fittings

PIPEPHASE allows you to specify the pipe fittings shown in Table 6-10 as flow devices within any link:

Table 6-10: Equipment Devices Modeled by PIPEPHASE

With the exception of the nozzle and venturimeter devices, all other fittings pressure drop equations are taken from the Crane59 manual. The nozzle and venturimeter pressure drop equations have been taken from Blevins.61 You are referred to these publications for further details concerning these formulations.

Two-Phase Flow Pressure Drop Corrections for Fittings

The pressure drop equations for the fittings given in Table 6-10. These equations can only be applied with any reliability to single-phase gas, or single-phase liquid flow. If a two-phase fluid flows through any of these devices, then the associated pressure drop tends to be higher than the single-phase flow equivalent.

Expansion Contraction

Valve Bend

Orifice Nozzle

Venturimeter Entrance

Exit Tee


In PIPEPHASE you have two options to calculate a factor which is subsequently used as a “two-phase multiplier” to the standard single-phase pressure drop equations. These are referred to as the CHISHOLM or HOMOGENEOUS methods. The general format for this correction factor can be represented as:

(6-76)

where:

Chisholm Method

The two-phase pressure drop across a fitting using the Chisholm model, PTP, is given by:

(6-77)

when:

The factor C in equation (6-77) is given by:

(6-78)

(6-79)

(6-80)

where:

= the two-phase multiplier for the standard pressure drop equation

KFITTING = the (single-phase) K-factor for the fitting device

KmulFITTING = the (single-phase) K-multiplier (KMUL), or L/d, for the fitting device

fd = friction factor of the device

PL and PG = Pressure drops over the fitting with only single-phase liquid or single-phase gas flowing respectively at the same total mass rate as the two-phase fluid

v = Specific volume of the gas (vG), liquid (vL), or the difference between both phases (vG - vL = vGL)

n = Constant in PIPEPHASE that is set to zero (the default value of is therefore 1.00). The user is able to alter the value of directly in the fittings statements

PFITTING KFITTING2

2gc---------=

KmulFITTING

fd2

2gc-------------=

PTP

PL------------- 1 C

X---- 1

X2

------+ += =

C C2 – lg

g

------

0.5

+g

l

-----

0.5 l

g

-----

0.5

+=

XPL

PG-----------

0.5=

0.5 22 n–

2– =


Changing either the or C2 default values is only recommended when users are experienced in the application of the Chisholm correlations. These default values have been chosen to be conservative for a majority of applications.

Homogeneous Model

The homogeneous model requires no user input, and the value appropriate to the device is defined as:

(6-81)

where:

Completion

The method used to calculate the pressure drop depends on the fluid model and the completion type. Table 6-11a lists the pressure drop relationships for well completions. The Mcleod equations, used for open-perforated completions are based on radial flow. The Jones et al. equations, used for gravel-packed completions, are based on linear flow.

C2 = User-definable constant in the above expression that defaults to a value of 0.50 in PIPEPHASE (unless otherwise stated in 4)

x= Mass vapor quality

1GL

L--------- x+=



Table 6-11a: Completion ModelsCompletion Type

(Reference) Open-perforated (McLeod) Gravel-packed (Jones et al)

Turbulence Coefficient

Fluid Model

Blackoil or Single-phase liquid

Single-phase Gas

Compositional Multiphase or Steam/Water Mixtures

2.33x1010

kp1.201= 1.47x10

7kp

0.55=

Pin Pout– CqL DqL2

+=

C re rw ln

1.127x103–

2w

kphN---------------------------------------------------=

D

9.08x103– 1

re----- 1

rw------–

42h

2N

2----------------------------------------------------------=

Pin Pout– CqL DqL2

+=

CLL

1.127x103–

kgravA-------------------------------------------------=

D9.08x10

3– LL

A2

-----------------------------------------=

Pin2

Pout2

– Cqg Dqg2

+=

C1.424x10

3TZ re rw ln

kphN---------------------------------------------------------------=

D

3.16x1012TZ 1

re---- 1

rw------–

ln

42h

2N

2--------------------------------------------------------------------=

Pin2

Pout2

– Cqg Dqg2

+=

C 8.93x103TLZ

kgravA--------------------------------------=

D1.24x10

10– TLZ

A2

-----------------------------------------------=

Pin Pout– Cqm Dqm2

+=

Cm re rw ln

1.127m

x103–

2w

kphN-------------------------------------------------------=

D

9.08x103– 1

re----- 1

rw------–

42h

2N

2----------------------------------------------------------=

m

wm1 x– wmxwm1 x– wmx++

Lg-----------------------------------------------------------------------------=

m gx 1 x– L+=

Pin Pout– Cqm Dqm2

+=

CmL

1.127m

x103–

kgravA---------------------------------------------------=

D9.08x10

13– mL

A2

--------------------------------------------=


Table 6-11b: Symbology to Table 6-11aSymbols

A area open to flow, dp2hSPF/4, ft2 qg standard volumetric flow rate

d diameter qL, qm in situ volumetric flowrate, bbl/d

specific gravity (60 F/60 F) r radius, ft

h perforated interval, ft (Jones)penetration depth, ft (Mcleod)

density, lb/ft3

k permeability, (md) SPF shots/ft

L ft T temperature

viscosity, cP N number of holes in perforated interval

P pressure, psia w mass flowrate

x quality

Subscripts

e perforation plus crushed zone p open perforated area

grav gravel w perforation

g gas in inlet of completion

L liquid out outlet of completion

m mixture


Converging Network Simulations

This section aims to provide users of the network solution algorithms in PIPEPHASE with more information on practical ways of converging simulations when difficulties have been reported during the solution procedure.

Note: For an introduction on how the network solution methods operate, refer to 3:

User Requirements for this Section

To gain maximum benefit from this section, the user is assumed to have the following information available:

A network diagram or sketch was detailed in an earlier section of this chapter, How to Set up a Network Problem, p. 6-35. This diagram consists only of nodes, links, flow direction arrows, major devices and labels for clarity. It is important that, particularly on larger networks, the user check that the structure has been entered precisely according to the network diagram.

Note: The importance of having a network diagram cannot be overstressed. Technical support experience has shown that most problems relating to network simulations can be attributed to the poor initial set-up of the Structure Data Category of input.

You can have PIPEPHASE print out a simple box diagram of the structure once all data has been entered. This is achieved, in the General Data Category of input, by including the following statements:

• All pressures and flowrates (i.e., fixed or estimated) for each node should be clearly marked on the network diagram. Any subsequent changes in problem definition to assist convergence can be evaluated and implemented simply and quickly.

• A hard copy of the PIPEPHASE keyword file for the simulation. This allows you to check categories other than the Structure Data Category of input where necessary, so that all link flow device data can be referenced and checked.

• A list of the objectives of the simulation. You can then efficiently evaluate the impact on simulation objectives of all possible changes in network configuration.

Recommendations for converging network simulations are broken into two main categories.

CALC NORUN, ..... $$ Which stops PIPEPHASE from performing any calculations

PRINT CONNECT=FULL $$ Which activates the box structure diagram


• The first category gives general recommendations on how to set up networks to avoid the majority of problems during the solution procedure (i.e., preventative mea-sures).

• The second category provides more specific examples on network algorithm anoma-lies, and provides direction on how to interpret warning or error messages. This allows you to take any appropriate action necessary in order to achieve a solution.

General Recommendations

Simulation Input Granularity

Within the simulation itself, you must make common sense decisions concerning which flow devices are important to the simulation and which are not. For high pres-sure drop systems such as in long pipe runs, it is unlikely that simulating all fittings in every pipe run will enhance the simulation accuracy by any substantial degree. However, in low pressure drop systems, the simulation of every part of each pipe configuration may be critical to ascertaining the pressure drop accurately.

Estimates of Pressure and Flowrate

PIPEPHASE requires that estimates be supplied for either pressure and/or flowrate at each node, depending on the configuration of network and type of network algo-rithm that have been chosen. These estimates may all be supplied by the user, or you may specify (by not supplying estimates) that the program generates its own esti-mates where required, or a mixture of user-supplied and program-generated esti-mates may be specified. Estimates of flowrates for sources or sinks must be supplied by the user. Generally, you should supply pressure estimates only at nodes where a value can be confidently predicted (normally from field data and experience, or from other simulation runs). When estimates are supplied for pressure, you should ensure that the data is consistent with the flow directions and are consistent with other esti-mated values. When you supply estimates for flowrates, you should ensure that they are in approximate material balance with other estimated and fixed values.

• The Use of Junctions

The junction node should only be used in the following circumstances:

• The network structure dictates that one or more links are joining together or splitting apart. The junction is used here as a structural node.

• The user requires the generation of a phase envelope or two-phase flow map or flash report (compositional runs only) at a particular point in the network which is not described by any other node.

There are no other reasons for using junction nodes in addition to the given above. As discussed in Chapter 2, Using PIPEPHASE, the network algorithm is a simulta-


neous solution procedure. Adding unnecessary nodes only serves to increase the size of the matrix and so increase computing time. Therefore, while there is a tendency for “neatness” in input by splitting long links into smaller links using junctions, the user should bear in mind the possibility of detrimental effect on the simulation solu-tion procedure

Note: Outside of their use in the above list, junctions must be viewed as simulation devices only, and should not be confused with any physical representation of the plant.

Network Structure and Topology

Following are basic guidelines for good simulation practice when setting up any net-work simulation in PIPEPHASE:

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

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

• Unnecessary nodes (see The Use of Junctions above) should be eliminated.

• Definitions of flow direction in link statements should be checked for consis-tency with the overall network source(s)-to-sink(s) logic. Flow direction should not form closed flow loops.

• When using the network algorithm, as a general rule, network simulations solve more easily when more flowrates are input as fixed values, rather than fixing pressure values. This is especially true in networks which include loops. By swapping a fixed pressure for a fixed flowrate, you may still investigate the effect of varying this pressure using multiple CASESTUDYs.

• Items of process equipment within links should have performances specified so that their outlet conditions do not conflict with other nodes in the system. See Figure 6-21 for a typical example of this erroneous input.

Figure 6-21: Process Equipment Definition


In this case, since node A and B flowrates have been fixed, the subsequent fixing of both pump outlet pressures ensures that it is impossible to balance pressures at junc-tion C. This type of incorrect setup can be more easily identified in existing simula-tions, or avoided in future simulations, by referring to a previously prepared network diagram.

Maximum Number of Iterations (NM)

By default, PIPEPHASE will use 20 iterations to try to reach a solution to network problems. For large and complex systems, it is recommended that this number be reduced so that minimum time is spent waiting for a potentially diverging simulation to finish. This is particularly true for calculation-intensive compositional fluid simu-lations. In the Network Data Category of input, if you specify SOLUTION MAX-ITER=5, then the simulation will stop after five iterations (if it has not already reached solution). You may then diagnose whether additional iterations will produce a solution, or alternatively which actions should be taken in order to achieve conver-gence. By using restart files, you can continue the simulation where it stopped.

Iteration History

You should include the statement PRINT ITER in the General Data Category of input when running new or problematical simulations. This will ensure that the con-vergence history is printed both to the screen and to the output file, to facilitate fault diagnosis.

Specific Recommendations

Link Shut-Ins (NM)

A link shut-in is the description given to a link (a series of devices between two nodes) which PIPEPHASE has closed down and removed completely from the solu-tion procedure.

Link shut-ins occur during the network solution procedure in these circumstances.

• When there is flow in the reverse direction through a check valve.

• When insignificant flowrates are determined for a link within a loop configura-tion.

Inspect the iteration history and look more closely at the first link which is causing problems. If there are no obvious anomalies in the input after careful inspection, you should first try to reformulate the local boundary node pressure and flowrate defini-tions (for example, swap a fixed pressure for a fixed flowrate). Secondly, you should enter link flowrate estimates for all local links. When an internal link shut-in occurs, you may also see the “link shut-in” error message.


There is also an option in the Methods Data Category of input to instruct PIPEP-HASE not to reverse flows during solution (the NOFR keyword). Activating this feature will assist particularly in loop configurations where the direction of flow is known (for example cooling water networks). However, this option can generally be detrimental in systems where the estimated flow directions are incorrect.

Flowrate Estimation in Links

In addition to ensuring that the best estimates are supplied for node pressures and flowrates (or having PIPEPHASE generate estimates automatically), you may also provide link flowrate estimates to assist PIPEPHASE’s own auto estimation logic. PIPEPHASE has four methods for allocating link flowrates prior to the start of the solution procedure:

• Flow Allocation Model 1

This is the default method, and allocates initial link flows based on the diameter of the first pipe device that appears in the link. Therefore, once PIPEPHASE’s node pressure estimation logic/user-supplied estimates has initialized each node with a starting pressure, the link flowrate is found from the relation:

(6-82)

where:

subscript i represents the ith link

You should therefore ensure that the first pipe device input to each link structure is approximately representative of the bulk of the link.


This model assigns a flowrate to each link based on the relative frictional resistance in that link, or:

(6-83)

where:

subscript j represents the jth link

Qi2

di5Pi

Qj2 di

5

li-------

i 1=

n

j

Pj


In this model, each pipe (from pipe 1 to pipe n) of diameter d and length l in the link is taken into account in the link flow allocations.

Note: The flow allocation models 1 and 2 can be specified in the Methods Data Category of input of input using the FLOWALLOCATION keyword (FLOWALLOCATION=1 and FLOWALLOCATION=2 respectively)


According to this model, PIPEPHASE initializes the nodal pressure distribution and link flows of the network by solving an approximation to the equations that describe the conservation of mass at network nodes. The solution algorithm that is used for this model is essentially identical to that used by preliminary solution stage of the MBAL flow balance algorithm. The only difference is that in multiphase systems the Beggs-Brill-Moody (BBM) model is used to approximate the pressure drop across links. In single-phase systems, the BBM model reduces to the Colebrook equation used in the preliminary solution stage of the MBAL algorithm. Again, as is the case with the MBAL algorithm, only average link fluid properties (e.g., qualities, no-slip holdup, viscosities, and densities) are used in the traverse calculations that accom-pany this flow allocation model.


When selected, this option allows you to use initial estimates to the network solution that are provided in a restart file. The restart file must be named filename.rst. For example if the run file is named run.inp, the restart file must be named run.rst.

The PBAL algorithm of PIPEPHASE generates a restart file (with the rst suffix) at the termination of a run. This file presents data on pressures and temperatures, as well as data on link flows. You can modify this file, and can use it to initialize a sub-sequent run with the PIPEPHASE algorithm.

• User-supplied Link Flow Estimates

To assist convergence, you may input link flow estimates to methods 1 and 2, in order to selectively override internally generated values and so assist conver-gence. The use of user-defined link flow estimates should be necessary only in sensitive and/or highly looped networks. There are different requirements for each of the two flow allocations models. With the first model, described above, the concept of a spur link in a simulation must be introduced.

The term spur link is used in PIPEPHASE to denote a link or set of links which, for the purpose of the simultaneous network solution algorithm, can be decou-pled from the rest of the network.


Figure 6-22: The Spur Link

In Figure 6-22, the sinks J, L and M all have fixed flowrates. Taking the individ-ual link KM as an example, the sink node M flowrate is known and therefore its pressure must be calculated. This calculation is based only on the calculated pressure at junction node K.

Therefore link KM can be “left out” of the network solution until the nodes on which iteration must be performed (including node K) have reached a solution. KM is thus known as a spur link. Similarly, since sink nodes L and M also have known flowrates, the section of links to the right of junction node I then form a larger spur link, since all of their pressure calculations rely on the solution to the pressure at node I.

For flow allocation model 1, you must supply link rate estimates for all non-spur links. If any non-spur link flowrate estimations are not input by the user, then all flowrate estimates revert back to those predicted by flow allocation model 1, and any other user entries are ignored. If you are unsure which links are spur links in the network, then set SOLUTION MAXITER=0 (in the Meth-ods Data Category of input), with PRINT ITER (in the General Data Category of input). Those links printed out after the iteration history are the spur links (see the Intermediate Printout Example in 5).

For flow allocation model 2, there is more flexibility in allowing you to selec-tively override internal program link rate estimates. If you wish to take advan-tage of this, then only those links which form the outlet of a node can be supplied with user estimates, and all links arising from the same node must be given estimates.


Figure 6-23: Link Flowrate Estimates

As a theoretical example, for the network defined in Figure 6-23, you have dis-covered that by using PIPEPHASE’s flow allocation model 2, the output link CF is being allocated only 10% of the total inlet rate to junction node C. Using this model then subsequently causes convergence problems, as indicated in the convergence history. You may then override this initial internal flow allocation by supplying the value directly in the link statement. You must remember that all links emanating from the node which produces link CF must also be given rate estimates. In this example, this means that link CE must be given an esti-mate in addition to CF. The reason for this logic is that PIPEPHASE uses the ratio of outflowing link rate estimates in allocating the actual link rate estimates. Let us continue with this example, and track PIPEPHASE’s processes up to the beginning of the simultaneous solution procedure. Let us first assume that the flowrates at nodes A and B in Figure 6-23 have user-supplied estimates of 100 and 80 lb/hr respectively, and also that you expect the flows in links CF and CE to be approximately equal. PIPEPHASE then follows the steps given in the paragraphs below:

• First, PIPEPHASE takes all fixed and user-estimated pressures at each node, and based on these pressures produces its own estimates for nodes which have not been supplied with any pressure value.

• Second, PIPEPHASE uses the flow allocation model (in this example, model 2) to assign flowrates to each link. If you have supplied any flowrates, (in this case let us assume that you have given estimates of 80 lb/hr for each of the links CF and CE emanating from node C) then these will be summed together and a ratio produced. In this case, the sum is 160 lb/hr, and the ratio is 50% to link CF and 50% to link CE.


• Third, PIPEPHASE performs a material balance using estimated and fixed flow-rates at the source and sink nodes. In this example, the source rate estimates of 180 lb/hr total are fed to node C, where the user-defined split ratio of 50/50 is used to produce link rate estimates of 90 and 90 lb/hr in links CF and CE (there-fore overriding the user’s incorrect estimates of 80 lb/hr per link). The material balance algorithm is also an iterative process and will override user-defined sink rate estimates where necessary to be consistent with fixed values elsewhere in the network. This completes the initial estimation procedure for PIPEPHASE, and the program will then continue to perform the simultaneous solution proce-dure until either convergence or the maximum iteration limit is reached.

Guidelines on User-Estimation of Link Flow Rates

If you suspect that PIPEPHASE’s flow allocation models are producing link flowrate estimates which are causing the problem not to converge, then the values that are predicted after mass balance (i.e., the third step in the above procedure) can be inspected in the output, by specifying the statement SOLUTION MAXITER=0 in the Methods Data Category of input.

For flow allocation model 1, user link flowrate estimates should be in material balance. Convergence of the network problem may be placed completely off-course if errors are inadvertently made by the user in setting up unbalanced link rates for all non-spur links.

If the solution/iteration history to a problem suggests that by giving more iterations a solution will be achieved, it is advised to use selected final link rates from the previous solution, together with flow allocation model 1.

Recommendations for Networks which Include Loops

Guidelines presented previously in this chapter also apply to systems involving loops. You should also be acquainted with the following guidelines so as to maximize the possibility of solving even the most complex looped network.

• Hydrostatic Impossibilities

A common mistake in loop definitions is in the user defining inconsistent pipe eleva-tions in the links which comprise the loop. Referring to the example in Figure 6-24, loop A-B-C has been defined by the user such that the absolute elevation of the pipe device “x” in link B-C is different (in this case, less) than the absolute elevation of the pipe device “y” in link A-C. This is an impossible situation, and PIPEPHASE will indicate, in the iteration history, that a constant maximum error has been reached.


Figure 6-24: Elevation Inconsistency in Loop

• Jump-Over Piping

So-called “jump-overs” are short pipe runs that connect longer, parallel pipes in order that flows in each pipe are relatively well-balanced. These jump-over pipes are usually of no hydrostatic significance, and the loop that is created by virtue of their inclusion in the simulation can be eliminated by making the two junction nodes into one, as is shown inFigure 6-25, with negligible loss in simulation accuracy.

Figure 6-25: Jump-Over Line Simulation Technique

• General Tips for Loops Where the Flow Direction is Known or Unknown

Networks which include loops fall into two basic categories – those which all link flow directions are known, and those which one or more link flow directions are unknown.


• Interval Halving and Loops Where Flow Direction is Known

In these simulations, you need to check all of the input link flow direction logic in order to ensure all FROM=…., TO=…. link statements are as required, and to spec-ify the keyword NOFR in the Methods Data Category of input. This will ensure that PIPEPHASE will not attempt to reverse flows during the solution procedure, and therefore should assist in converging with these network types. A typical situation encountered where the user has instructed PIPEPHASE not to reverse flow direc-tions (see also Using Regulators, below) is in interval halving. In links where a flow reversal cannot occur, PIPEPHASE will instead halve the absolute change in flow-rate that has been predicted by the solution algorithm in order to try to prevent flow reversal in the link.

Figure 6-26 shows a refinery case where the user has fixed the flowrates of sinks D and E at values of 5,000 and 10,000 bpd respectively. In addition, the user has speci-fied in the input that no flow reversals are allowed (the schematic is part of a larger network, upstream, and the FROM=..., TO=... definitions are as indicated in the first diagram).

For iteration 1 (i=1), the upstream network is producing a feed to node A of 15,000 bpd, which is split accordingly to satisfy the two fixed sink flowrates. The flow direction in loop link BC is as input by the user.

In the next iteration, 2, (i=2), the upstream network increases the next estimate for the flow to node A to 20,000 bpd. PIPEPHASE then splits the flow according to its solution algorithm, and finds that its first attempt requires the loop link CB to change in flow direction in order to satisfy the fixed sink rate of 5000 bpd. Since the user has instructed PIPEPHASE not to reverse flows from iteration to iteration, the program then interval halves, by subtracting the CB link rate in iteration 2 (-333 bpd) from that in iteration 1 (+1000 bpd), and dividing the result by two. Therefore:

New interval halved link rate = 1000 - (1000 + 333)/2 = +333.5 bpd

This new value results in a flowrate of 4,665 bpd required in link AB in order to sat-isfy the fixed sink rate D rate, and consequently requires 10,333.5 bpd in link AC. This then demands that a flowrate of 15,000 bpd be fed to node A. Subsequently the new iteration information is fed back to the upstream network.

It should be noted that if the user has incorrectly defined a loop link flow direction, and then instructed PIPEPHASE (via NOFR or using a REGULATOR device) not to reverse flows during simulation, the network will fail to converge. The interval halv-ing will continue until almost zero flow is found in the link. An error message is then produced (or the link is shut in), and the user may inspect the iteration history to find which link is producing the error by identifying the link which has near-zero flow.


Figure 6-26: Interval Halving

• Loops Where Flow Direction is Unknown

Some network simulations include more than one loop configuration, where one or more of the loops contains links in which the flow direction is not known to the user.

This is especially true in existing designs, and must be addressed in a special man-ner. Problems are usually not found in looped networks until at least one simulation has been run. If the problem has not converged, the user can generate the full itera-tion output (using PRINT ITER in the General Data Category of input). The output can be inspected to diagnose problems. Figure 6-27 shows a typical example of the maximum error (i.e., pressure imbalance as reported in the iteration history) against number of iterations:

Figure 6-27: Looped Network – Example Flow Reversal Problem


This example shows that the network is converging successfully up until the point indicated by the arrow. When this position has been reached, PIPEPHASE decides to reverse the flow direction in one or more links of a particular loop. By reversing the flow in this/these links, the solution path begins to diverge and a final solution becomes unachievable. The user may inspect the iteration history to ascertain in which link the flow reversal occurred first. Placing a regulator device in that link will prevent the flow reversal.

• Using Regulators

A regulator is a device which is used to maintain flow at a fixed downstream pres-sure. In flow through such a regulator, if the inlet pressure is greater than the user-set pressure, then the outlet pressure becomes the user-set pressure, and if the inlet pres-sure is less than the set pressure, then the outlet pressure is set equal to the inlet pres-sure. In network configurations involving loops, however, its use is almost exclusively tailored to preventing flow reversals in loop links. Regulators are used in looped networks mainly to assist convergence

Note: A general rule-of-thumb is to restrict the use of regulators to an intelligent minimum. The user should rarely need more than one such device installed per loop to assist in convergence.

To prevent link flow reversal during solution, you should set the regulator outlet pressure (in the flow direction) to an unrealistically high value (e.g., 9999 psig). This action enables the use of the regulator as a convergence aid without affecting the pressure traverse calculation in that link.

Regulators generally are of greatest use in situations where loop link flow reversals cause a circular flow path (i.e., effectively a closed flow loop), or where a particular flow reversal during solution causes a direct or indirect (via another link) problem divergence. Both of these situations can be identified by close inspection of the iter-ation history.

A simple use of a regulator can be seen in Figure 6-28, where the flow directions are known.


Figure 6-28: Simple Use of Regulators to Assist Convergence

Use of two regulators in this example prevents the situation where flow travels from node B to node C via one loop, and back to node B via the other.

Other Problems In Network Convergence

• Problem Solution Does Not Exist

There are network configurations that will not solve in any circumstances. These networks are physically unrealistic and a solution will therefore never be obtained. You can see where these situations have been encountered by messages which include:

ERROR - ALL UNKNOWN PRESSURE AND RATES ARE WITHIN 0.100 PER-CENT OF UPPER OR LOWER BOUNDS (i.e., program limits have been reached for pressure and rate values)

or

ERROR - SINGULAR MATRIX AT ITERATION *** NO PIVOT FOUND IN COLUMN

(i.e., PIPEPHASE’s solution matrix has one or more zero values for pressures and/or flowrates)

In either of these cases a previously drawn network diagram will identify any errors made in the configuration.


Specific Keyword Assistance in Converging Networks

The default parameters for the PBAL and MBAL algorithms are selected to achieve satisfactory convergence for representative networks. However, you can encounter cases in which the defaults require modification for successful solution of network flows.

PBAL Algorithm

This algorithm is sufficient for the overwhelming majority of problems you will encounter. Nevertheless, there are cases in which the parameters that govern the performance of this algorithm require your adjustment. The following section offers assistance on the use of the adjustable parameters that modify the performance of the PBAL algorithm.

The parameters that have the greatest effect on the performance of PBAL are the parameters that control

• the initial estimation of link flows and junction pressures, and

• extent of damping (also relaxation) of the PBAL algorithm.

The former is controlled by adjustment of the FLOW allocation parameter, while the latter is controlled by adjustment of the QDAMP, PDAMP, HALVINGS, NOLOOP and NOFR keywords.

• Initial Solution Estimation. The FLOWALLOC keyword controls the procedure used by PIPEPHASE to generate an initial estimate of the flowfield prior to the use of the PBAL iteration procedure. In general, the performance of PBAL improves with the selection of an allocation method that generates initial estimates of flows and pressures that are closer to the converged solution of the network flow field.


The FLOWALLOC keyword allows the user to specify one of four flow allocation algorithms. The default is FLOWALLOC=1. In circumstances in which the default allocation method is not satisfactory, you have the option of selecting two other flow allocation models (FLOW=2 and FLOW=3), as well as the ability to generate initial estimates from a previously generated restart file (FLOW=4). As described previ-ously, the allocation option (FLOW=3) requires the solution of an approximate; but, nonlinear network flowfield. Because of the nonlinearity, there are several adjustable parameters that can be used to control the convergence performance of the FLOW=3 allocation model. These are described below. The FLOW=4 option requires the use of a previously generated restart file, and examples of its use are discussed below.

• PBAL Under-Relaxation Procedures. Even with the provided flow allocation models, there can still be circumstances in which initial estimates are not sufficiently close for the Newton-Raphson iterations used by PBAL to converge to a solution. In these circumstances, a damping or under-relaxation of the Newton-Raphson steps can be required to obtain a solution. The adjustable parameters that effectively con-trol the amount of damping in the Newton Raphson procedure include: QDAMP, PDAMP, HALVINGS, NOLOOP, and NOFR. Some comments follow.

• QDAMP and PDAMP. These keywords control the magnitude of the Newton-Raphson corrections to the link flow distribution and the nodal pressure distribu-tion that are computed by PBAL. The use of QDAMP is appropriate when PBAL is unable to converge because of large changes in link flows. Similarly, the use of PDAMP is appropriate when PBAL fails to converge because of large changes in nodal pressures in successive Newton-Raphson iterations.

Trial and error is required to select an appropriate magnitude for QDAMP and/or PDAMP. If these magnitudes are set too low, then PBAL can require an excessive amount of computational time to obtain a solution. On the other hand, if these magnitudes are set too high, then PBAL can rapidly diverge from the network solution. Clearly, the danger exists that through use of excessively large values of QDAMP/PDAMP that an initially adequate (and occasionally difficult to obtain) initial estimate can be lost within a few PBAL iterations. Because of this, you are advised to save the restart file associated with the initial estimate, and use the restart allocation option (FLOW=4) in the trial and error searches for QDAMP/PDAMP.

• HALVINGS. This parameter controls the number of interval halvings that are used by PBAL to correct the magnitude of changes to Newton Raphson correc-tions in the flow and pressure fields. The default value is (HALVINGS=3). Increasing this parameter can effectively shrink the magnitude of the Newton-Raphson corrections in PBAL. You are generally not advised to modify this parameter.


• NOLOOP. As described in the manual this option effectively scales the magni-tude of Newton-Raphson corrections in PBAL so as to prevent the formation of closed loops. The option can be appropriate in circumstances in which flow reversals are expected in looped pipe networks.

• NOFR. This option is used to prevent the occurrence of flow reversals in suc-cessive Newton-Raphson iterations of the PBAL algorithm. This option is appropriate in cases where PBAL fails to converge because of excessive flow reversals, and the final distribution of link flows is known.

• FLOWALLOC=3. As described above, this algorithm estimates the initial net-work flowfield by solution of approximate; but, nonlinear equations that con-serve mass at network junctions. The equations are approximate because

• the Beggs-Brill-Moody (BBM) model with no acceleration is used to approxi-mate the pressure drop across links, and

• fluid properties are only evaluated at a fixed number of points (usually only one) in a traverse across a link.

The nonlinear equations in the initialization scheme are solved by Newton-Raphson iteration. Generally, the default parameters in the SOLUTION and TOLERANCE cards are sufficient to ensure that the initialization procedures converges to a solution. However, there can be circumstances in which adjust-ment of the default settings are required. Some suggestions follow.

• Convergence. You can monitor the convergence of the solution procedure used in the allocation method through use of the ITER keyword on the PRINT card. Residuals in the changes of the pressure field between successive Newton Raph-son iterations, and the magnitude of flow imbalances at network nodes are dis-played in the iteration history display for the method. Generally the allocation model will converge to a solution, so long as the displayed residuals of pressure and flow decrease, more or less continuously, with successive iterations.

Occasionally, the residuals of either one or both of the displayed quantities will exhibit a sustained increase with successive iterations. In these circumstances the method will not converge, unless adjustments are made to default settings on the SOLUTION card. The primary candidates for keyword adjustment are:

a) the extent of under-relaxation, or damping, to the Newton Raphson iterations through use of the DAMP keyword,

b) the maximum number of allowed iterations through the use of the SUBITERA-TION keyword, and


c) in multiphase flows in networks (or gathering systems) with large elevation changes the angle that governs the transition between no-slip and slip flow through use of the SLIP keyword.

• DAMP. In circumstances in which the iteration procedure fails, the user is advised to increase the amount of damping or under-relaxation through the use of the DAMP keyword. The default value of DAMP is 0.25. Damping is increased by decreasing the value of DAMP, e.g., by equating DAMP to 0.05 instead of 0.25. The advantage to increased damping is increased stability in the solution procedure. The disadvantage is a possible increased requirement for computational time through an increase in the number of iterations to achieve a solution.

• SUBITERATION. The default number of iterations for this method is 200. This number might not be sufficient for the amount of damping that is required to obtain a solution. In these circumstances the value of SUBITERATION should be increased.

• SLIP. The solution procedure used for FLOWALLOC=3, can occasionally fail with multiphase flows in networks or gathering systems with large elevation changes. This occurs because the BBM method used to estimate link capacities can admit more than one solution in links with elevation change. This problem is alleviated by use of the no-slip BBM model in links in which the elevation change exceeds the angle define by SLIP.

• Tolerances. Occasionally, a display of the iteration history for the iterations associated with FLOWALLOC=3 will show that the residuals have reached a lower limit (for pressure change and/or flow imbalance) that exceeds the limits on the TOLERANCE statement. This implies that the allocation model has reached a best possible solution for the network. To reduce the number of subit-erations that are performed, on subsequent runs of PIPEPHASE, you can either reduce the number of subiterations or can increase the values of PTOL and QTOL on the TOLERANCE statement.

There are also circumstances in which an examination of the residual history shows that the residuals for the allocation model are falling when either PTOL or QTOL are reached. This implies that by lowering the tolerances PTOL and QTOL, the user should be able to obtain an even better solution to the approximate network flow field. The effort to do this, however, is often not necessary, as the PBAL algorithm that follows the FLOWALLOC=3 initialization procedure does require an accurate initial solution estimate.

• Miscellaneous Assists to PBAL Convergence. The keywords CHOKE and WELLS on the SOLUTION statement, and the keyword QMIN on individual link


statements offer additional features that can help the PBAL algorithm to converge to a solution. The explanation is given below.

• CHOKE. The ability of the PBAL algorithm to converge to a solution of a pipe network is often strained by the presence of one or several chokes that operate in the regimes of critical flow. This occurs because the presence of chokes in criti-cal flow introduces a discontinuity into the pressure distribution within links.

6-29 below shows a typical choke performance curve. The Newton-Ransom method has no problem solving the network when the choke is in the sub-critical flow region. However, when the flow becomes critical, the Newton derivative approaches infinity and the N-R method mathematically breaks down. As a result the N-R solver has great difficulty finding a solution in the critical flow region.

Figure 6-29: Choke Performance Curve (Choke Outlet Pressure vs. Flow Rate)

In order to assist PBAL, there are 4 options:

The default method (CHOKE = 1) is to use an exponential broadening of the pressure transition that accompanies critical flow. The PIPEPHASE choke model substitutes the straight vertical line, denoting critical flow, with an exponential curve. This is the red dashed line shown in 6-29 above. In this way the Newton-Ransom solver finds it easier to calculate a critical flow value for the choke. Option two (CHOKE = 2) replaces the exponential curve with a straight line (i.e. blue dashed line shown in 6-29 above)

Engineers simulating a PIPEPHASE network containing chokes in critical flow will often modify the slopes of these lines to make it easier for the N-R solver to reach a converged solution. The slope is adjusted by specifying the "Rate Tolerance".


See "Max Possible Error" illustrated in 6-29.

Clearly as the Rate Tolerance is increased, the solver finds it easier to reach a solution. However, the critical flow rate calculated using this method has the potential to exceed the actual critical flow rate by a fraction of the value specified in the Rate Tolerance window. Generally the relative size of this flow rate error is small when compared to the total flow rate of the well. This approach ensures the results generated give an accurate picture of the true potential of the well.

In option 3 (CHOKE = 3), the user activates an algorithm in PIPEPHASE such that it calculates the critical flow rate for the link before solving the network. This method is only applicable for Source links where the pressure has been fixed. For such simulations, "DP from Network" is the recommended choke method as its’ the most mathematically stable and rigorous.

Figure 6-30: “DP from Network” Method

Figure 6-30: By selecting "DP from Network", (Choke=3) the user forces PIPEPHASE to calculate the critical flow rate for a given Pin and set this as the Qmax constraint for the link. The Critical flow rate is defined as the intersection of the Tubing Performance Curve and the Critical Choke Performance Curve.

Once PIPEPHASE calculates the Critical flow rate, Qmax for the link is set to this value. In other words it sets a constraint, which specified that as long as the BHP remains constant, the flow rate in the link cannot exceed the calculated Critical flow rate. This acts as a safety net to ensure that PIPEPHASE can never calculate an unrealistic flow rate through the choke (i.e. for a given bottom hole pressure PipePhase will always calculate a flow rate less than or equal to the Critical flow rate for the link). The Qmax


logic enables PIPEPHASE to solve the Network rigorously and in a very stable manner while at the same time preserving the physics of the choke flow as expressed in the equations below.

(6-84)

(6-85)

where:

Pout = Pressure down stream of the Choke

Pin = Pressure upstream of the Choke

rc = Critical Pressure Ratio

Qc = Critical Flow Rate

Q = Flow rate through the choke

Note the Gilbert choke model only operates on the Critical Choke Performance Curve. The Gilbert coefficients determine the slope of this line. Fortunati, Perkins, and Ueda on the other hand can operate on the Critical Choke Performance Curve plus anywhere within the Sub-Critical Flow Region.

For "Critical Pressure Ratio", (i.e. CHOKE=4) a different convention is used. Instead of PIPEPHASE imposing constraints by way of an exponential or linear curve the following equation is used.

For Q > Qcritical

(6-86)

This convention makes for a stable network model as the choke outlet pressure is simply computed using above equation for the Critical Pressure Ratio. Ueda, Fortunati & Perkins models can all predict critical flow and an associated critical pressure ratio. The user can override the calculated critical pressure ratio by specifying a value in the Choke unit DEW.

Pout

Pin

--------- rc

Q Qc

Pout

Pin

--------- rc


Unfortunately as demonstrated in the diagram below, by calculating the outlet pressure of the choke based solely on the critical pressure ratio, there are cases where this method will quite happily predict flow rates through the choke far in excess of the real critical flow rate for a given bottom hole pressure. As a result, this method is not recommended when modeling chokes.

Figure 6-31: Choke Performance Curve

Figure 6-31: Choke Performance Curve as defined by Choke=4. Notice following this curve it is possible to predict flow rates through the choke far in excess of the actual critical flow rate. As a result, this method is not recommended when modeling chokes.

• WELLS. The occurrence of heading phenomena that accompanies upward, multiphase flows in wells, can give rise to convergence problems in PBAL. The WELLS option on the solution statement seeks to solve this problem by (1) determining the minimum heading flow that is allowed in wells with specified source pressures, and by (2) constraining flows in those wells to be greater than that minimum flow rate. PBAL shuts-off the well in the event that the minimum flow can not be maintained in the well.

• QMIN. This keyword appears on individual LINK statements. This keyword constrains the minimum flow in links to be greater than a user specifiable value. This feature can be useful in seeking the solution to network flows in which links not associated with wells can display heading phenomena.


MBAL Solution Algorithm

The MBAL solution algorithm offers an alternative to PBAL for the solution of single phase network flows. As with PBAL, the defaults that govern the operation of this algorithm can require adjustment for successful solution of network flow fields. Suggested keywords for modification include: RELAX, DAMP, SUBITERATION, QTOL, PTOL and TTOL. Explanations follow:

DAMP and RELAX. As with the Newton-Raphson procedure used with the FLOWALLOC=3 option of PBAL, under-relaxation of Newton-Raphson steps can be required with the MBAL algorithm. The keyword DAMP applies to the initial solution estimate used by MBAL (this is the same algorithm that is used in the PBAL initialization procedure FLOWALLOC=3), and the keyword RELAX applies to the non-linear MBAL solution procedure. The default value of both keywords is 0.25. A reduction in the value of these parameters is warranted in circumstances in which an examination of the residual history (either flow imbalances or nodal pres-sures) does not show a sustained decrease. Please see above comments for the use of the DAMP keyword in the FLOWALLOC=3 option of PBAL.

SUBITERATIONS. Because the MBAL algorithm is independent of PBAL, you must ensure that sufficient iterations are allocated for the chosen level of under-relaxation through either DAMP or RELAX for the desired solution tolerances to be attained. The default value of the parameter is 200.

QTOL, PTOL and TTOL. These define the required level of convergence for the nodal flows, and the changes in the pressure and temperature fields. You are advised, that often the application of the MBAL algorithm yields minimum values of these quantities that exceed the specified values of QTOL, PTOL and TTOL. Often this can not be changed. In these circumstances, you are advised to relax the solution requirements for the MBAL algorithm.


Sub-Network Algorithm

Introduction

In a network, PIPEPHASE allows the user to specify upstream pressure or flow rate to a Choke (MCHOK)/ Regulator (MREG) or the inlet pressure to a compressor (MCOMPRESSOR). When these specifications are invoked, PIPEPHASE automatically breaks the original network at the device inlet into two new separate subnetworks (pseudo-links). PIPEPHASE then uses the sub-network algorithm to rigorously solve the resultant network.

If MCHOK is specified, PIPEPHASE will calculate the choke size that is required to meet the specification. Similarly PIPEPHASE will calculate the Compressor Power if the MCOMP with specified inlet pressure is invoked.

Figure 6-32: Original Link

When the specification as mentioned above are invoked for the devices, subnetworks are formed with

• Upstream link containing all the devices before the break point

• Downstream link containing all the devices after the break point.

During the formation of subnetwork, a new sink (pseudo sink) is created for the upstream link and simultaneously a new source (pseudo-source) is created for the downstream link. The upstream link retains the original link name but the downstream link will be given an unique link name. The new nodes (pseudo-sink and pseudo-source) are also assigned internally generated unique names.

Many sub-networks will be created if several such devices are included in the network. At calculation time the sub-network containing the upstream link(s) is solved prior to the sub-network containing the downstream link(s). The flow coming out of the upstream link (pseudo sink) is transferred to the downstream link (pseudo source); prior to the calculation of the downstream sub-network pseudo link.

A B

Mreg or Mchok or Mcomp

Inlet Pressure or Flow specified

Link name = L1


Figure 6-33: Broken Links (Sub-Network)

To properly set up sub-network problems the following conditions must be met:

• Each pseudo-sink and pseudo-source pair must occur in separated sub-network.

• Each sub-network's boundary conditions must be such that each sub-network prob-lem is an independent well-posed network problem. Ensure that the boundary condi-tion of each sub-network honors the required Network Well-Posedness conditions.

• Each pseudo-link must have at-least one pressure loss device (not counting the MCHOK, MREG, or MCOMPRESSOR).

Some Network Well-Posedness conditions that needs to be met for each sub-network:

• At least one pressure in the network must be fixed.

• At least one sink or source must occur.

• Each link must have at least one device that has a consistent variation of pressure-drop as a function of flow rate (flow-pressure drop performance relationship).

Frequently Asked Questions

This section presents and answers those queries most commonly asked through SimSci’s worldwide technical support network. PIPEPHASE users and readers of this manual are encouraged to provide feedback on the content and layout of this section to ensure future editions of the manual are of practical use to the user.

A B

Mreg or Mchok or Mcomp

Pressure or flow specified sink

Link name = L1 Link name = ‘1’

‘2’ ‘ 3’

Flow specified source


FAQ 1: What are the merits of the K-factor and K-multiplier infitting pressure drops?

Referring back to equation 6-18 where the form of the frictional pressure loss in a pipe of circular cross-section was derived:

(6-87)

Integrating equation (6-87) over a section of pipe of length L gives:

(6-88)

If we now define the term “head”, which is gained or lost over a length of pipe L, as hL, where P = ghL (for each pressure drop term in equation (6-19)), then the velocity in a pipe changes at the expense of the “static”, or elevation head. Therefore the decrease in the elevation head due to velocity is known as the “velocity head”:

(6-89)

The flow of fluid through a valve or other pipe fitting, such as an elbow, will also result in a change in head. This may also be expressed in terms of the velocity head:

(6-90)

The loss term K in equation (6-90) is defined as the resistance coefficient, K-factor, or number of velocity heads. The K-factor, therefore, can be viewed as a constant for any particular valve or fitting, and independent of friction factor or Reynolds number. From equation (6-88), the frictional pressure drop over a straight section of pipe is similarly given by:

(6-91a)

where:

(6-91b)

dpdL------

FRICTION

fdv2

2gcdi--------------=

Pfdv2

2gcd------------=

HLv

2

2gc

--------=

HL Kv2

2gc

--------=

HL fLd---

v2

2gc

--------=

K fLd---=


(6-91c)

Therefore by equating equations (6-95) and (6-96), it can be seen that the K-factor is equivalent to (f L/d), where the ratio L/d is the equivalent length (in pipe diameters) of straight pipe that will cause the same pressure drop as the valve or fitting under the same flowing conditions.

Crane59 presents evidence that in valves and fittings the K-factor varies “…with size as does the friction factor, f, for straight clean commercial steel pipe at flow conditions resulting in a constant friction factor, and [the] equivalent length L/d tends toward a constant for the various sizes of a given line of valves or fittings at the same flow conditions.” This conclusion leads to the idea that instead of using a K-factor, the equivalent length, L/d, should instead be used as a constant multiplier of the friction factor. The value of the constant should then be derived from field test data and applicable to all sizes of the particular valve or fitting with which it is identified. In PIPEPHASE the equivalent length constant, as reported in standard publications such as Crane, is known as the K-multiplier (keyword KMUL).

In summary, therefore, the K-multiplier should always be chosen, if available, in preference over a K-factor value, since the K-factor varies with the size of the valve or fitting.

FAQ 2: Should one use “equivalent lengths” inside links with two-phaseflow to represent fitting pressure drops?

The “K-factor - pipe equivalent length” analogy was originally derived only for incompressible single phase flow (see previous FAQ), where the pressure drop is due only to friction. The analogy is also applicable for single phase compressible flow where velocities and velocity changes (i.e., acceleration) are low.

However, for two-phase flow in pipes the same analogy cannot be applied, and the use of equivalent pipe lengths is not recommended as good simulation practice. The “equivalent length” value (i.e., the K-multiplier) multiplied by the prevailing friction factor is not the same as the true K-factor because the accelerational effects are not considered in its evaluation. In typical piping system simulations these acceleration terms may be significant and can cause pressure drops to be predicted which are much higher than the K-factor method. In the case of two-phase flow, there is no direct established procedure, equivalent to that presented in the previous FAQ, to derive the “equivalent length” analogy, and therefore it should not be used in these situations. A two-phase multiplier, j, is used in PIPEPHASE (see a previous section in this chapter on Fittings for further information) to correct the single phase pressure drop equation (6-91a) for a fitting device to account for two-phase flow.

KMULLd---=


FAQ 3: How do you explain a pressure recovery over an expansion device?

An expansion is a device in PIPEPHASE which models the pressure change in a fluid moving from one pipe diameter to another of larger diameter. The pressure change over an expansion across which fluid is moving from one circular pipe to another circular pipe of larger diameter (as opposed to a pipe exit, where no velocity recovery can occur), consists of two terms:

1. Velocity head change

2. Friction head loss

Qualitatively, the velocity head tends to cause a pressure increase, and the friction component causes a pressure decrease. The pressure drop equation over an expansion for a single phase fluid can be shown to be (see Crane59, p2-11):

(6-92)

where:

subscripts 1 and 2 refer to the small and large diameter points respectively, and

Kexp = the user-supplied K-factor

If we define as the ratio A1/A2, then it can be seen by inspection of equation (6-92) that if 1-2- Kexp > 0 then P2 > P1 and there is a pressure recovery.

This phenomenon occurs when the 1-2, or velocity head loss is larger than the frictional pressure loss over the expansion (as calculated by the Crane methods). Pressure rises over expansion devices are generally unusual, but if they occur in network simulations, then PIPEPHASE may have trouble solving pressure balances because of this behavior. In these cases the user should replace these devices with other devices exhibiting equivalent, but continuous, pressure vs. flow behavior, such as DPDT devices or alternative fittings with similar K-factors.

(6-93)

Since PIPEPHASE evaluates conditions at the inlet conditions to the fitting, the velocity head term can be expanded:

(6-94)

P 1A1

A2

-----2

– Kexp– Lv

2

2gc

---------=

P– Kexp

v12

2gc

-------- v2 2gc

-----------------+=

v2

2gc

-----------------L

2gc

-------- v22 v1

2– =


From the Conservation of Momentum equation, and using inlet densities:

(6-95)

(6-96)

(6-97)

(6-98)

Substituting equation (6-98) into equation (6-94), and reversing the signs gives equation (6-83).

FAQ 4: Why does PIPEPHASE have two network solutionmethods (Flare and Network)?

The Network solution method in PIPEPHASE is a general purpose algorithm, geared towards solving as wide a variety of networks as possible. In the case of flare networks, the nature of such systems dictates the possibility of very high velocities and perhaps critical flow in parts of the system. The general purpose network algorithm (PBAL) operates in a forward-marching, simultaneous manner. Therefore if a discontinuity were to occur at the end of a link in this algorithm, there may conceivably be multiple solutions for the true outlet pressure of that node. In the Flare algorithm the algorithm works backwards from the flare base, and therefore a check can be made at the beginning of each link for critical flow. The upstream pressure which would be required to achieve this condition can then be calculated.

FAQ 5: What is the relation between discharge coefficients used in valvesizing and the K-factor used to define pressure drop?

PIPEPHASE models the pressure drop across a device/fitting as:

(6-99)

where:

p = device pressure drop

q/A = mass flux per unit area

A1v1 A2v2=

A12

A22

-----v2

2

v12

----=

A1

A2

-----

2

1–v2

2 v12–

v12

---------------=

v2 2gc

-----------------Lv1

2

2gc

-----------A1

A2

-----

2

1–=

p

KqA---

2

2----------------=


The device K-factor that appears in equation (6-99) can be related to the discharge coefficient Kd used to size valves in the API 520 (1993) formula for liquid relief:

(6-100)

where:

In the limit of single-phase liquid flow, equation (6-100) can be combined with equation (6-99) to yield the following relation for K-factor in terms of the valve discharge coefficient Kd and viscosity correction factor Kv:

(6-101a)

In the limit of high Reynolds number flows Kv approaches 1, so that equation (6-101a) can be approximated as:

(6-101b)

FAQ 6: What is the relation between the flow coefficient of a valve (Cv)and the K-factor for the valve?

The flow coefficient Cv of a valve is defined as the volumetric flux of water, in either UK or US gallons per minute, at a temperature of 60° and at a pressure drop of one pound per square inch (1 psia) across the valve (Crane, 1988).

The following expressions relate the resistance coefficient K to Cv:

For valve flows in UK gallons per minute:

= no-slip fluid density

= two-phase fluid multiplier

K = device K-factor

A = Required effective discharge area (in2)

Q = Flowrate (US gal/min)

Kd = Effective coefficient of discharge for valve

Kw = Correction factor due to back pressure (Kw=1 for conventional valves)

Kv = Correction factor due to viscosity as determined from Figure 32 of API 520 (1993)

G Specific gravity of the liquid at the flowing temperature referred to water = 1.0 at 70 F

P Valve pressure drop

AQ

38KdKwKv

-------------------------- GP-------=

K 1

Kd2Kv

2-------------=

K 1

Kd2

------=


(6-102a)

For valve flows in US gallons per minute:

(6-102b)

where:

d = diameter of the value (in)

Clearly, the coefficient Cv can be related to the discharge coefficient Kd of a valve through equations (6-102a) and (6-102b).

FAQ 7: What is the relation between the Joule-Thomson effectand adiabatic flashing?

Gases can often be cooled when subject to a sufficiently rapid expansion. The cooling phenomenon, which is termed the Joule-Thomson effect, forms the basis of a number of refrigeration processes. In everyday use, the Joule-Thomson effect can be seen in the temperature fall that accompanies the rapid release of the contents of an aerosol can.

When flowing gases are allowed to expand from a higher pressure to a lower pressure without producing work, i.e., across an insulated valve, the heat transfer effects are negligible and the flow can be approximated as adiabatic. Furthermore, if the changes in kinetic and potential energy are negligible, then the expansion can be approximated as isenthalpic: see equation (6-4a). Thus:

(6-103)

where:

H1 and H2 = the enthalpies upstream and downstream of the expansion

The temperature drop that accompanies the pressure drop across the expansion is termed the Joule-Thomson67 effect. In the limit of incremental changes in pressure, the temperature change across the expansion is quantified by the Joule-Thomson coefficient:

(6-104)

where:

Cv24.9d2

K----------------=

Cv29.9d2

K----------------=

H H2 H1–=

JTTP

------

H=


JT = Joule-Thomson coefficient

Note: JT can be either positive or negative. In an ideal gas, JT is zero. The Joule-Thomson effect occurs in those gases for which JT is positive.

FAQ 8: How can I make PIPEPHASE use my own mixture physical property data in compositional fluid-type simulations?

When running single-link or network-type simulations using the compositional fluid model, physical and thermodynamic properties are generated automatically by PIPEPHASE’s transport and thermodynamic methods, using information from pure component databanks and/or built-in predictive property correlations.

Users may occasionally prefer to use their own values for certain physical properties, such as mixture fluid density, mixture vapor thermal conductivity, etc., They can do this by using the PVTGEN option on the CALCULATION statement in the General Data Category of input.

By using the PVTGEN option, the user can instruct PIPEPHASE to suppress any thermophysical property calculations and instead generate a separate file containing all PVT data required for the subsequent simulation. The flow chart outlining this procedure is shown below in Figure 6-34, using a single link example, of filename TEST.INP:

Figure 6-34: Flowchart for Problem TEST.INP

For this example, let us assume that the user wishes to override PIPEPHASE-generated values for liquid density. The step-wise procedure for achieving this is:


Construct the PIPEPHASE input file so as to generate a PVT property data file, TEST.PVT. Refer to 4, for the keyword constructs and see the following TEST.INP file as an example. Note that when using the CALC ...PVTGEN option the entry of any device data in the Structure Data Category of input is disallowed, and that in the PVT Property Data Category of input only one source can have property data generated over a user-defined temperature and pressure range. This means that in network simulations where there is more than one source composition, this method is inapplicable as a one-run solution, and the user must split the system up into one-source-composition sub-structures and run each concurrently. In entering the range of temperatures and pressures over which the property data tables are to be generated, the user must ensure all simulation conditions are covered, and must pay particular attention to two-phase systems where a sudden phase transition may occur. In these cases the temperature range must be input such that smaller temperature increments are specified over the boiling range of the fluid.

TEST.INP

TITL PROJ=PVT EX, PROB=MANNUAL, DATE=JUN94$DESC This file generates a .PVT file which is to be usedDESC in a subsequent run. Note that device data input is notDESC permitted for any .PVT file generation runs.$DIME PETRO,TEMP=C,PRES=KPA,RATE(M)=MOLH,RATE(W)=LBHR,* RATE(LV)=GPM,RATE(GV)=CFD,LENG=FT,IN,DENS=SPGR, * VISC=CP,DUTY=BTUH,POWER=HP,VELO=FPSCALC COMPOSITIONAL, PVTGENDEFA TAMB=85.PRINT DEVICE=PART,INPUT=FULL,CONNECT=NONE,PLOT=NONE,FLASH=NONE,ITER$PVT PROPERTY DATA SET SETN=1,VISC(C,CST)=150,2.2/250,.9 GENERATE SOURCE=S1,SETN=1,TEMP=100,150,200,250,300,* PRES=40,80,120,160,180,200,240 * PRINT=LDEN,LVIS $COMPONENT DATA LIBID 1,NC12/2,DOWG PETRO 3,DOW2,300,0.8100,425$METHODS DATA THERMO SYSTEM=SRK$STRUCTURE DATA SOURCE NAME=S1,PRES=181,TEMP=200,RATE(W,ESTI)=760000,* COMP=1,0.11/2,0.8/3,0.09, SETN=1 $ SINK NAME=SK1,PRES=181,RATE(W,ESTI)=760000 $ LINK NAME=L1,F=S1,T=SK1$END

The file TEST.PVT which is generated from step (1) is shown below (in abridged format for clarity). PIPEPHASE uses the data in this file in step (3) when the original file TEST.INP is re-run. The data contained within the file are in fixed format, and the units of measure for each property are also fixed. Since in this example the user wishes to


override liquid density information (to make all values of density at all specified temperature and pressure ranges equal to 50 lb/ft3), the new values are manually input by the user, overwriting those internally generated:

TEST.PVT

6 1 COMPOSITIONAL TABLE 1 INTRP 0 EXTRP 6 TEMP 5.19670E+02 6.71670E+02 7.61670E+02 8.51670E+02 9.41670E+02 1.03167E+03 8 PRESS 5.80152E+00 1.16030E+01 1.46959E+01 1.74046E+01 2.32061E+01 2.61068E+01 2.90076E+01 3.48091E+01 3 COMP 1.10000E-01 8.00000E-01 9.00000E-02 0 BUB-T 0 DEW-T 0 WAT-T 0 BUB-P 0 DEW-P 0 WAT-P AMW 2.12138E+02 TCRIT 1.44092E+03 PCRIT 3.45631E+02 1 PHASE 2 2 2 2 2 2 2 2 2 PHASE 2 2 2 2 2 2 2 2 3 PHASE 2 2 2 2 2 2 2 2 4 PHASE 2 2 2 2 2 2 2 2 5 PHASE 3 2 2 2 2 2 2 2 6 PHASE 1 3 3 3 3 2 2 2 1 VFRAC 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 2 VFRAC 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 3 VFRAC 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 4 VFRAC 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 5 VFRAC 7.75616E-01 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 6 VFRAC 1.00000E+00 9.25658E-01 8.43983E-01 6.98157E-01 7.42643E-02 0.00000E+00 0.00000E+00 0.00000E+00 1 LFRAC 1.00000E+00 1.00000E+00 1.00000E+00 1.00000E+00 1.00000E+00 1.00000E+00 1.00000E+00 1.00000E+00 2 LFRAC 1.00000E+00 1.00000E+00 1.00000E+00 1.00000E+00 1.00000E+00 1.00000E+00 1.00000E+00 1.00000E+00 3 LFRAC 1.00000E+00 1.00000E+00 1.00000E+00 1.00000E+00 1.00000E+00 1.00000E+00 1.00000E+00 1.00000E+00 4 LFRAC 1.00000E+00 1.00000E+00 1.00000E+00 1.00000E+00 1.00000E+00 1.00000E+00 1.00000E+00 1.00000E+00 5 LFRAC 2.24384E-01 1.00000E+00 1.00000E+00 1.00000E+00 1.00000E+00 1.00000E+00 1.00000E+00 1.00000E+00 6 LFRAC 0.00000E+00 7.43422E-02 1.56017E-01 3.01843E-01 9.25736E-01 1.00000E+00 1.00000E+00 1.00000E+00 1 VMW 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 2 VMW 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 3 VMW 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 4 VMW 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 5 VMW 2.04269E+02 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 6 VMW 2.12138E+02 2.08475E+02 2.06323E+02 2.04524E+02 1.96965E+02 0.00000E+00 0.00000E+00 0.00000E+00 1 LMW 2.12138E+02 2.12138E+02 2.12138E+02 2.12138E+02 2.12138E+02 2.12138E+02 2.12138E+02 2.12138E+02 2 LMW 2.12138E+02 2.12138E+02 2.12138E+02 2.12138E+02 2.12138E+02 2.12138E+02 2.12138E+02 2.12138E+02 3 LMW 2.12138E+02 2.12138E+02 2.12138E+02 2.12138E+02 2.12138E+02


2.12138E+02 2.12138E+02 2.12138E+02 4 LMW 2.12138E+02 2.12138E+02 2.12138E+02 2.12138E+02 2.12138E+02 2.12138E+02 2.12138E+02 2.12138E+02 5 LMW 2.39336E+02 2.12138E+02 2.12138E+02 2.12138E+02 2.12138E+02 2.12138E+02 2.12138E+02 2.12138E+02 6 LMW 0.00000E+00 2.57746E+02 2.43593E+02 2.29748E+02 2.13355E+02 2.12138E+02 2.12138E+02 2.12138E+02 1 VDENS 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 2 VDENS 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 3 VDENS 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 4 VDENS 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 5 VDENS 1.19806E-01 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 6 VDENS 1.13306E-01 2.26543E-01 2.86308E-01 3.38524E-01 4.40871E-01 0.00000E+00 0.00000E+00 0.00000E+00 1 LDENS 6.32289E+01 6.32318E+01 6.32334E+01 6.32348E+01 6.32377E+01 6.32392E+01 6.32406E+01 6.32436E+01 2 LDENS 5.96295E+01 5.96336E+01 5.96358E+01 5.96377E+01 5.96418E+01 5.96439E+01 5.96459E+01 5.96500E+01 3 LDENS 5.75040E+01 5.75087E+01 5.75112E+01 5.75133E+01 5.75180E+01 5.75203E+01 5.75226E+01 5.75272E+01 4 LDENS 5.52552E+01 5.52608E+01 5.52637E+01 5.52664E+01 5.52719E+01 5.52747E+01 5.52775E+01 5.52831E+01 5 LDENS 4.95052E+01 5.27863E+01 5.27903E+01 5.27938E+01 5.28012E+01 5.28049E+01 5.28086E+01 5.28161E+01 6 LDENS 0.00000E+00 4.46015E+01 4.63987E+01 4.85330E+01 5.02346E+01 5.00085E+01 5.00138E+01 5.00244E+01 1 WDENS 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 2 WDENS 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 3 WDENS 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 4 WDENS 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 5 WDENS 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 6 WDENS 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 1 VENTH 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 2 VENTH 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 3 VENTH 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 4 VENTH 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 5 VENTH 9.91163E+03 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 6 VENTH 1.88580E+04 1.48200E+04 1.29382E+04 1.26260E+04 2.36420E+04 0.00000E+00 0.00000E+00 0.00000E+00 1 LENTH -2.26520E+04 -2.26476E+04 -2.26452E+04 -2.26432E+04 -2.26388E+04 -2.26365E+04 -2.26343E+04 -2.26299E+04 2 LENTH -1.72126E+04 -1.72085E+04 -1.72062E+04 -1.72043E+04 -1.72002E+04 -1.71981E+04 -1.71961E+04 -1.71919E+04 3 LENTH -1.37436E+04 -1.37398E+04 -1.37377E+04 -1.37358E+04 -1.37321E+04 -1.37301E+04 -1.37282E+04 -1.37243E+04 4 LENTH -1.00723E+04 -1.00689E+04 -1.00670E+04 -1.00654E+04 -1.00620E+04 -1.00603E+04 -1.00586E+04 -1.00552E+04 5 LENTH 1.18035E+04 -6.17741E+03 -6.17622E+03 -6.17498E+03 -6.17230E+03 -6.17096E+03 -6.16969E+03 -6.16693E+03 6 LENTH 0.00000E+00 4.08897E+04 2.52328E+04 9.91483E+03 -2.56503E+03 -2.03245E+03 -2.03175E+03 -2.03032E+03 1 WENTH 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 2 WENTH 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 3 WENTH 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00


0.00000E+00 0.00000E+00 0.00000E+00 4 WENTH 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 5 WENTH 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 6 WENTH 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 1 VENTR 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 2 VENTR 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 3 VENTR 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 4 VENTR 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 5 VENTR 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 6 VENTR 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 1 LENTR 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 2 LENTR 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 3 LENTR 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 4 LENTR 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 5 LENTR 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 6 LENTR 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 1 WENTR 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 2 WENTR 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 3 WENTR 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 4 WENTR 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 5 WENTR 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 6 WENTR 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 1 VVISC 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 2 VVISC 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 3 VVISC 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 4 VVISC 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 5 VVISC 8.96134E-03 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 6 VVISC 9.11876E-03 9.48192E-03 9.68948E-03 9.81842E-03 9.81146E-03 0.00000E+00 0.00000E+00 0.00000E+00 1 LVISC 5.89668E+01 5.89696E+01 5.89711E+01 5.89723E+01 5.89751E+01 5.89765E+01 5.89778E+01 5.89806E+01 2 LVISC 4.41840E+00 4.41871E+00 4.41887E+00 4.41901E+00 4.41932E+00 4.41947E+00 4.41962E+00 4.41992E+00 3 LVISC 2.02648E+00 2.02664E+00 2.02673E+00 2.02680E+00 2.02697E+00 2.02705E+00 2.02713E+00 2.02729E+00 4 LVISC 1.16371E+00 1.16383E+00 1.16389E+00 1.16395E+00 1.16406E+00 1.16412E+00 1.16418E+00 1.16430E+00 5 LVISC 7.13697E-01 7.61000E-01 7.61058E-01 7.61108E-01 7.61215E-01 7.61268E-01 7.61322E-01 7.61429E-01 6 LVISC 0.00000E+00 4.81529E-01 5.00933E-01 5.23975E-01 5.42346E-01 5.39905E-01 5.39962E-01 5.40076E-01 1 WVISC 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 2 WVISC 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 3 WVISC 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00


0.00000E+00 0.00000E+00 0.00000E+00 4 WVISC 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 5 WVISC 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 6 WVISC 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 1 VCOND 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 2 VCOND 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 3 VCOND 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 4 VCOND 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 5 VCOND 1.38256E-02 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 6 VCOND 1.55415E-02 1.61361E-02 1.64906E-02 1.67451E-02 1.72699E-02 0.00000E+00 0.00000E+00 0.00000E+00 1 LCOND 6.39367E-02 6.39571E-02 6.39671E-02 6.39755E-02 6.39928E-02 6.40011E-02 6.40092E-02 6.40251E-02 2 LCOND 5.79183E-02 5.79404E-02 5.79511E-02 5.79601E-02 5.79784E-02 5.79872E-02 5.79958E-02 5.80124E-02 3 LCOND 5.41696E-02 5.41940E-02 5.42058E-02 5.42157E-02 5.42357E-02 5.42452E-02 5.42546E-02 5.42726E-02 4 LCOND 5.02529E-02 5.02810E-02 5.02944E-02 5.03056E-02 5.03284E-02 5.03392E-02 5.03498E-02 5.03701E-02 5 LCOND 4.70671E-02 4.61722E-02 4.61888E-02 4.62024E-02 4.62299E-02 4.62430E-02 4.62556E-02 4.62798E-02 6 LCOND 0.00000E+00 4.40660E-02 4.32161E-02 4.25578E-02 4.26664E-02 4.29022E-02 4.29182E-02 4.29487E-02 1 WCOND 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 2 WCOND 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 3 WCOND 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 4 WCOND 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 5 WCOND 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 6 WCOND 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 1 LSURF 3.94058E+01 3.94058E+01 3.94058E+01 3.94058E+01 3.94058E+01 3.94058E+01 3.94058E+01 3.94058E+01 2 LSURF 3.17187E+01 3.17187E+01 3.17187E+01 3.17187E+01 3.17187E+01 3.17187E+01 3.17187E+01 3.17187E+01 3 LSURF 2.73074E+01 2.73074E+01 2.73074E+01 2.73074E+01 2.73074E+01 2.73074E+01 2.73074E+01 2.73074E+01 4 LSURF 2.30138E+01 2.30138E+01 2.30138E+01 2.30138E+01 2.30138E+01 2.30138E+01 2.30138E+01 2.30138E+01 5 LSURF 1.80006E+01 1.88521E+01 1.88521E+01 1.88521E+01 1.88521E+01 1.88521E+01 1.88521E+01 1.88521E+01 6 LSURF 0.00000E+00 1.37379E+01 1.42221E+01 1.48285E+01 1.50154E+01 1.48410E+01 1.48410E+01 1.48410E+01 1 WSURF 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 2 WSURF 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 3 WSURF 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 4 WSURF 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 5 WSURF 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 6 WSURF 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+00 0.00000E+000 0 END-OF-FILE

Again, referring to 4, the original TEST.INP file should be modified so as to:


• Eliminate the PVTGEN keyword from the CALC... statement.

• Replace the PVT Property Data Category of input GENERATE statement with the statement FILE SETN=1. This ensures the declared SET NUMBERS match between TEST.INP and TEST.PVT files.

• Add all relevant device data to the link statement(s).

TEST.INP

TITL PROJ=PVT EX, PROB=PVT READ, DATE=JUN94$DESCDESC This file reads in the previously generated .PVT DESC$DIME PETRO,TEMP=C,PRES=KPA,RATE(M)=MOLH,RATE(W)=LBHR,* RATE(LV)=GPM,RATE(GV)=CFD,LENG=FT,IN,DENS=SPGR, * VISC=CP,DUTY=BTUH,POWER=HP,VELO=FPSCALC COMPOSITIONALDEFA TAMB=85.PRINT DEVICE=PART,INPUT=FULL,CONNECT=NONE,PLOT=NONE,FLASH=NONE,ITER$PVT PROPERTY DATA SET SETN=1 $COMPONENT DATA LIBID 1,NC12/2,DOWG PETRO 3,DOW2,300,0.8100,425$METHODS DATA THERMO SYSTEM=SRK$STRUCTURE DATA SOURCE NAME=S1,PRES=181,TEMP=200,RATE(W,ESTI)=700000,* COMP=1,0.11/2,0.8/3,0.09, SETN=1 $ SINK NAME=SK1,PRES=181,RATE(W,ESTI)=700000 $ LINK NAME=L1,F=S1,T=SK1 PIPE ID=16 ,LENGTH=40 PIPE ID=16 ,LENGTH=28 VALV IDIN=16,IDOUT=16,K=533 PUMP CURVE(GPM,FT)=1000,341,35/2000,337,57/* 3000,328,73/4000,315,81/5000,284,85 PIPE ID=12,LENGTH=80 PUMP CURVE(GPM,FT)=1000,341,35/2000,337,57/* 3000,328,73/4000,315,81/5000,284,85 PIPE ID=12,LENGTH=100 DPDT NAME=DP1,CURVE(,KPA,C)=198600,-43,0/396000,-172,0/79200,-688,0 HEATER NAME=H1,TOUT=260 CONTR IDIN=12,IDOUT=6 PIPE ID=6,LENGTH=1000 DPDT NAME=DP2,CURVE(,KPA,C)=214500,-34.5,0/429000,-138,0/858000,-552,0 COOLER NAME=CRX1,TOUT=205 PIPE ID=6,LENGTH=1000 $END


FAQ 9: How can I increase the speed of execution of a simulation run?

For simulations involving large networks and using a compositional fluid model, calculation times may be large. If several cases of such simulation types require running in succession, then time-saving measures should be taken seriously in completing a study. Calculation time-saving measures, with comments, are given below.

• If the fluid in the simulation is known to remain in only the liquid or in only the gas phase for all conditions, then a qualifier may be used in the CALCULATION COM-POSITIONAL statement which disables any flash calculations being performed (i.e., COMP(GAS) or COMP(LIQ)). This will speed up execution time by up an order of magnitude.

• If only one source composition is being used, the PVTGEN option (explained in FAQ 8 and detailed in 4) can be invoked where PIPEPHASE will neither perform flash calculations nor property calculations and instead look up any required value from a pre-generated table (.PVT file). This table can be generated and saved for use in subsequent simulations, or can be generated and used in the same simulation (in which case the .PVT file will not be saved). Significant calculation time enhance-ments can be expected using this procedure. However, care must be taken in the gen-eration of the property tables to ensure that phase transitions are adequately bounded by temperature and pressure points, and upper and lower tabulated limits cover the expected simulation range.

If the simulation involves low velocity fluids, then the accelerational component of the overall fluid pressure drop will not be significant, and by invoking CALC NOACCELERATION this calculation is disabled. Only marginal calculation speed increases can be expected using this option. This option should be used only as a last resort and has been included in this FAQ section for completeness.

FAQ 10: What are the *.GR1, *.GR2, *.GR3, and *.GR4 files that areproduced when I run PC PIPEPHASE?

The *.GR? files are ASCII text files which are used by the PC Graphical User Interface to plot information to the screen.

• The *.GR1 file contains link plot information.

• The *.GR2 file contains node summary information.

• The *.GR3 file contains information for the link phase envelope.

• The *.GR4 file contains information from depressuring vessel simulations.


Data Transfer System

PIPEPHASE is able to read in stream data from the output of a PRO/II simulation. A block diagram showing how this information link works is shown below in Figure 6-35.

Figure 6-35: Block Diagram of Data Transfer System

Procedure for Accessing PRO/II Stream Data

Assuming there is a PRO/II simulation input file named PROII.INP, you should first run the PRO/II simulation. Include the statement DBASE DATA=STREAM in the General Data Category of input (see example input files below). This will produce a text file named PROII.P2I (alongside normally produced output files) which contains information for all input and calculated streams in a format which is readable to both PRO/II and PIPEPHASE.

The PROII.P2I file should then be copied from the PRO/II user directory into the PIPEPHASE user directory, and the file should be renamed to be the same as the target PIPEPHASE input file name, but keeping the extension .P2I. In this example, let us assume that our PIPEPHASE input file is named TEST.INP. The stream data file PROII.P2I should then be renamed TEST.P2I.

The source data input in the Structure Data Category of input in the PIPEPHASE file must include one of the keywords documented below, depending on which data is to be retrieved from the PRO/II stream output. The PRO/II file which generated the TEST.P2I file is shown below:

TITLE PROJECT=SAMPLE,PROBLEM=DATA,USER=SIMSCI,DATE=1994DESC FOR USE IN STREAM DATA TO EXAMPLEDIME SI, TEMP=C, PRES=KPA, XDEN=SPGRPRINT RATE=M, STREAM=ALL, INPUT=PARTDBASE DATA=STREAM*


COMPONENT DATA* LIBID 1,NITROGEN/2,CO2/3,METHANE/4,ETHANE/5,PROPANE/* 6,IBUTANE/7,BUTANE/8,IPENTANE/9,PENTANE/10,HEXANE* PETRO 11,BP135,120.,0.757,135/ * 12,BP260,200.,0.836,260/ * 13,BP500,500.,0.950,500*THERMODYNAMIC DATA* METHOD SYSTEM(VLE)=SRK,SET=SET01,DEFAULT*STREAM DATA* PROP STREAM = 1,TEMP=200,PRES=2000,PHASE=M,RATE(M)=7200, * COMP(M)= 1,180.004 / 2,190.904/ 3,1443.03/ 4,902.218/* 5,721.914 / 6,76.5715/ 7,279.406/ 8,94.7819/* 9,162.403 /10,153.303/11,1191.03/12,902.218/* 13,902.218 ,NORMALIZE* PROP STREAM=R1R,REFS=1,RATE(M)=1 PROP STREAM=R2R,REFS=1,RATE(M)=1 PROP STREAM=FD-1,TEMP=40,PRES=2000,PHASE=M,* RATE(M)=16000,* COMP(M)=4,4000/5,8000/6,4000, NORMALIZE* NAME 1,MAIN,FEED/R1R,BALANCE-1/R2R,BALANCE-2/* FD-1,SEC-FEED/OV8,COL-OVERHEAD/BT8,COL-BOTTOMS*UNIT OPERATIONS* FLASH UID=F1,NAME=FEED FLASH FEED 1,7 PROD V=3 ADIA DP=0 METHOD SET=SET01 $ SET01* HX UID=HX1,NAME=AFTERCOOL-1 HOT FEED=3,R1R,V=4,METH=SET01 COLD FEED=FD-1,R2R,V=PR-2,METH=SET01 OPER HTEMP=90* FLASH UID=F2,NAME=STAGE 1 SEP FEED 4 PROD V=6,L=5 ISO TEMP=10,PRES=1000 METHOD SET=SET01* SPLITTER UID=SP1,NAME=UNIT-SP1 FEED 5 PROD M=7,M=8 SPEC STREAM=7,RATE(M), * RATIO, * REFFEED,RATE(M) * VALUE=0.1 METHOD SET=SET01 $ SET01*

COLUMN UID=COL2,NAME=FRAC-002 PARAM TRAY=22,IO=20 FEED 8,9,NOTSEP PROD OVHD=OV8,BTMS=BT8,4289 COND TYPE=BUBB,PRESS=1000 DUTY 1,1,-40/2,22,40 PSPEC TOP=1000 PRINT PROP=PART,ITER=PART,XYDATA ESTI MODEL=SIMPLE,CTEMP=-100,TTEMP=-50,BTEMP=50,RTEMP=140, * RRATIO=2 SPEC COLUMN=COL2,TRAY=1,PHASE=L,RATE(M),* RATIO, * STREAM=OV8, RATE(M), *


VALUE=2 SPEC STREAM=BT8,RATE(M), * VALUE=4289 VARY DUTY = 1,2 TOLER ENTH = 0.001 METHOD SET=SET01,22* END

Extracting Component Data and Temperature for aSource – PRO2 Keyword

Let us assume that the PRO/II file (above) contains stream 6 (a vapor product from the stage 1 separator F2) which PIPEPHASE requires to be its source KA. The structure of the PIPEPHASE file would then be as shown below, with the PRO2 keyword used on the SOURCE statement.

TITLE PROJECT=IPM,PROBLEM=DATA,USER=SIMSCI,DATE=1994DESC STREAM DATA TRANSFER FROM PRO/II ‘SAMPLE.INP’DIMEN SI,TEMP=C,PRES=KPA,DENS=SPGRFCODE PIPE=BBMDEFAULT TAMBIENT(F)=100,ROUGH(IN)=0.0018,THKPIP(IN)=0.55,* CONINS(BTUFTF)=0.019,0.23,0.4,THKINS(IN)=2,0.125,2.03CALC SING,COMPPRINT DEVICE=FULL,INPUT=FULL,PROP=NONE,CONN=NONE,PLOT=FULL,FLASH=FULL$COMPONENT DATA LIBID 1,NITROGEN/2,CO2/3,METHANE/4,ETHANE/5,PROPANE/* 6,IBUTANE/7,BUTANE/8,IPENTANE/9,PENTANE/10,HEXANE$ PETRO 11,BP135,120.,0.757,135/ * 12,BP260,200.,0.836,260/ * 13,BP500,500.,0.950,500$ THERMODYNAMIC DATA METHOD SYSTEM=SRK, TRANS=PETRO$STRUCTURE DATA SOURCE NAME=KA,RATE(W,LBHR)=58358,PRES(PSIG)=2000,NOCHECK,PRO2=6$ SINK NAME=SNK, PRES(ESTI,PSIG)=1000$ LINK NAME=LNK1,FROM=KA,TO=SNK PIPE ID(IN)=4,LENGTH(FT)=10 EXPA IDIN(IN)=4.,IDOUT(IN)=8. PIPE ID(IN)=7.981,LENGTH(FT)=325 CONT IDIN(IN)=8,IDOUT(IN)=4 PIPE ID(IN)=4,LENGTH(FT)=0.5 EXIT IDPIPE(IN)=4$ END

In this case, the temperature and composition of stream 6 in the PRO/II file is used automatically to complement data entered for source node KA.

Extracting Component Data, Pressure and Temperature for aSource – PR2F Keyword

In this case, the structure of the PIPEPHASE file would be as shown below, with the PR2F keyword used on the SOURCE statement.

TITLE PROJECT=IPM,PROBLEM=DATA,USER=SIMSCI,DATE=1994DESC STREAM DATA TRANSFER FROM PRO/II ‘SAMPLE.INP’DIMEN SI,TEMP=C,PRES=KPA,DENS=SPGR



FCODE PIPE=BBMDEFAULT TAMBIENT(F)=100,ROUGH(IN)=0.0018,THKPIP(IN)=0.55,* CONINS(BTUFTF)=0.019,0.23,0.4,THKINS(IN)=2,0.125,2.03CALC SING,COMPPRINT DEVICE=FULL,INPUT=FULL,PROP=NONE,CONN=NONE,PLOT=FULL,FLASH=FULL$COMPONENT DATA LIBID 1,NITROGEN/2,CO2/3,METHANE/4,ETHANE/5,PROPANE/* 6,IBUTANE/7,BUTANE/8,IPENTANE/9,PENTANE/10,HEXANE$ PETRO 11,BP135,120.,0.757,135/ * 12,BP260,200.,0.836,260/ * 13,BP500,500.,0.950,500$ THERMODYNAMIC DATA METHOD SYSTEM=SRK, TRANS=PETRO$STRUCTURE DATA SOURCE NAME=KA,RATE(W,LBHR)=58358,NOCHECK,PR2F=6$ SINK NAME=SNK, PRES(ESTI,PSIG)=1000$ LINK NAME=LNK1,FROM=KA,TO=SNK PIPE ID(IN)=4,LENGTH(FT)=10 EXPA IDIN(IN)=4.,IDOUT(IN)=8. PIPE ID(IN)=7.981,LENGTH(FT)=325 CONT IDIN(IN)=8,IDOUT(IN)=4 PIPE ID(IN)=4,LENGTH(FT)=0.5 EXIT IDPIPE(IN)=4$ END

In this case, the source KA is using the temperature, pressure and composition of PRO/II stream 6 as fixed values in the simulation.

Extracting Pressure Estimate, Component Data, and Temperature for aSource – PR2E Keyword

In this case, the structure of the PIPEPHASE file would then be as shown below, with the PR2E keyword used on the SOURCE statement.

TITLE PROJECT=IPM,PROBLEM=DATA,USER=SIMSCI,DATE=1994DESC STREAM DATA TRANSFER FROM PRO/II ‘SAMPLE.INP’DIMEN SI,TEMP=C,PRES=KPA,DENS=SPGRFCODE PIPE=BBMDEFAULT TAMBIENT(F)=100,ROUGH(IN)=0.0018,THKPIP(IN)=0.55,* CONINS(BTUFTF)=0.019,0.23,0.4,THKINS(IN)=2,0.125,2.03CALC COMP,NETWORKPRINT DEVICE=FULL,INPUT=FULL,PROP=NONE,CONN=NONE,PLOT=FULL,FLASH=FULL$COMPONENT DATA LIBID 1,NITROGEN/2,CO2/3,METHANE/4,ETHANE/5,PROPANE/* 6,IBUTANE/7,BUTANE/8,IPENTANE/9,PENTANE/10,HEXANE$ PETRO 11,BP135,120.,0.757,135/ * 12,BP260,200.,0.836,260/ * 13,BP500,500.,0.950,500$ THERMODYNAMIC DATA METHOD SYSTEM=SRK, TRANS=PETRONETWORK DATA SOLUTION PBAL$STRUCTURE DATA SOURCE NAME=KA,RATE(W,LBHR)=58358,NOCHECK,PR2E=6$ SINK NAME=SNK, PRES(PSIG)=1000,RATE(ESTI)=1$

LINK NAME=LNK1,FROM=KA,TO=SNK PIPE ID(IN)=4,LENGTH(FT)=10 EXPA IDIN(IN)=4.,IDOUT(IN)=8. PIPE ID(IN)=7.981,LENGTH(FT)=325 CONT IDIN(IN)=8,IDOUT(IN)=4 PIPE ID(IN)=4,LENGTH(FT)=0.5 EXIT IDPIPE(IN)=4$ END

Here, the component data and temperature of PRO/II stream 6 are used as fixed values, where the pressure from stream 6 is used as an estimate value.

Restrictions on the Use of the Stream Data Transfer Facility

• DIMENSIONS must be declared to be the same in both PRO/II and PIPEPHASE input files. Local units of measure can be used to override the global defaults at any location in either program, so that the user need not be constrained.

• The Component Data Category of input must be consistent in both PRO/II and PIPEPHASE input files. The total number of components declared in the Compo-nent Data Category of input of the PRO/II input file must not exceed 50. Therefore library (LIBID), user-supplied (NONLIB), pseudo- (PETRO) and assay (via TBPCUTS) components must number in total less than or equal to 50. For pseudocomponents, the defined properties should be similar in both input files. When simulating with assay-defined data, it is recommended that you create the input file from the P2I file generated by the PRO/II run. This ensures that the pseudocomponents in PIPEPHASE are consistent with the PRO/II input file.

• The Thermodynamic Data Category of input must be the same or similar in both PRO/II and PIPEPHASE input files.

• In the PIPEPHASE Structure Data Category of input, those values that are to be replaced by the PRO/II stream must be absent from the statement. Also, the keyword NOCHECK must appear before the PRO2, PR2E and PR2F keywords on the SOURCE statement for correct operation.



Chapter 7 Component Data Summary

About This Chapter

This section provides an overview of the Component Data Category. Detailed documentation, along with examples of common usage of all the component features, is contained in a separate document, the SIMSCI Component and Thermodynamic Data Input Manual. Unless noted otherwise, sections referred to in this chapter are located in Chapter 1 of the SIMSCI Component and Thermodynamic Data Input Manual.

General Information

The Component Data category defines the pure and pseudocomponents in the problem and, if necessary, defines or modifies component properties. All components encountered in a problem, except for assay stream components, must be defined in this category. Streams defined by distillation assay curves in the Stream Data category are broken into pseudocomponents based on the rules defined in the Component Data category.

Using keyword input, PRO/II accepts an unlimited number of components.

PRO/II Component Library

PRO/II comes with an extensive pure component data base of over 1,750 components, tabulated in Sections 1.3-1.5 of the SIMSCI Component and Thermodynamic Data Input Manual. All components capable of vapor-liquid phase behavior have sufficient information to be used with generalized K-value predictors and density calculations. Most components have built in transport property correlations. A majority of PRO/II simulations with pure components use this library exclusively and require no additional pure component data. Refer to the PRO/II Reference Manual for additional details on the structure of the pure component data base and the information it contains.


Non-Library Components

Components not found in the PRO/II library may be entered as NONLIBRARY components. The format for entering user components is straightorward, however users who do this regularly or need help in estimating unknown required properties should use SIMSCI’s Property Data Management functionality present in PRO/II with PROVISION to assist the user in determining all necessary component properties and develop a keyword file segment in PRO/II ready form.

Petroleum Components

PRO/II handles petroleum components using industry standard characterization techniques. PRO/II estimates all required component data given two out of three of molecular weight, boiling point, or gravity.

Refer to the SIMSCI Component and Thermodynamic Data Input Manual for instructions on how to enter basic PETROLEUM data, how to change the default characterization procedures, and entering stream assay data.

Solid Components

PRO/II handles solids with particle size distributions and user-defined attributes. See the SIMSCI Component and Thermodynamic Data Input Manual for information on property data requirements for solid components and associated input format. The SIMSCI Component and Thermodynamic Data Input Manual is also used to define particle size intervals and GENERAL attributes, and for entering actual solid component attribute values.

Component Properties

The user may define or override component properties for all components in the simulation. This includes components in the PRO/II component library, user-defined components, petroleum pseudocomponents and solid forming components. The properties include constants (such as molecular weight or critical properties), as well as temperature dependent properties (such as enthalpies in various phase states). Where appropriate, properties may be given on a mole or weight basis. Refer to Section 1.8 of the SIMSCI Component and Thermodynamic Data Input Manual for entering component property values.

UNIFAC Data

Section 1.9 of the SIMSCI Component and Thermodynamic Data Input Manual discusses the methods for assigning UNIFAC structural groups and van der Waals parameters for pure components. As discussed starting in Section 20 and in the PRO/II Reference Manual, UNIFAC provides a means of estimating liquid activity coefficients when actual VLE or LLE data are unavailable.

7-2 Component Data Summary

Category Heading Statement (required)

COMPONENT DATA

The COMPONENT DATA statement has no entries and is required for all PRO/II simulations.

Remaining COMPONENT Data Category Statements

The remaining Component Data category statements are discussed in the SIMSCI Component and Thermodynamic Data Input Manual.

• Component Definition

• Petroleum Component Characterizations

• Solid Attributes

• Component Properties

• Component Structural Data for UNIFAC

Category Heading Statement (required)

Component Definition (conditional - Section 1.2)

Petroleum Component Characterizations (optional - Section 15)

COMPONENT DATA

LIBID i, library name, library number, alias/...,{BANK=PROCESS, SIMSCI, DIPPR, bankid...}{FILL=SIMSCI}

NONLIBRARY i, name/...{FILL=SIMSCI}

PETROLEUM(densunit, tunit)

i, name, MW, std liquid density, NBP/ ...

PHASE DEFAULT= VL or LS or S or VLS,{VL= i, j,..., LS= i, j,...,S= i, j,..., VLS= i, j,...}

ASSAY FIT= SPLINE or QUADRATIC or PDF(NONE, IP, EP, BOTH)CHARACTERIZE = TWU or CAVETT or CAV80 or LK or HEAVYO,MW = TWU or CAV80 or LK or HEAVYO,CONVERSION=API94 or API87 or API63,CURVEFIT= VER6 or IMPRGRAVITY= WATSONK or PRE301,{TBPIP= 1, TBPEP= 98}, {NBP=LV or MID}

CUTPOINTS TBPCUTS= to, t1, ncuts {/t2, ncuts/...},{CUTSET=SIMSCI},{BLEND=name}, {DEFAULT}


Component Definition for Synfuel Components (optional - Section 15)

Solid Attributes (optional - Section 16)

Component Properties (optional - Section 17)

Component invariant properties and constants

SYNCOMP COMP#, {NAME, MW, DENS}, NBP, {TYPE, ZNUM, CNUM}

SYNLIQ(W or V or M)

COMP#, NAME, MW, DENS, NBP, P, O, N, A

ATTR COMP= i, {PSD= s0, s1,...,}GENERAL=10, {GNAME=text1,text2,...}

MW i, value/...

SPGR i, value/...

API i, value/...

NBP(unit) i, value/...

ACENTRIC i, value/...

VC(unit, M or WT) i, value/...

TC(unit) i, value/...

PC(unit) i, value/...

ZC i, value/...

RACKETT i, value/...

CNUM i, value/...

ZNUM i, value/...

DIPOLE(unit) i, value/...

RADIUS(unit) i, value/...

SOLUPARA i, value/...

MOLVOL(unit) i, value/...

STDDENSITY(unit) i, value/...

HCOMBUST(unit, M or WT) i, value/...

HVAPORIZE(unit, M or WT) i, value/...

HFUSION(unit, M or WT) i, value/...

NMP(unit) i, value/...

PTP(unit) i, value/...

TTP(unit) i, value/...

GHV(unit, M or WT) i, value/...

LHV(unit, M or WT) i, value/...

SVTB i, value/...

SLTB i, value/...

SLTM i, value/...

7-4 Component Data Summary

Multi-property entries

Component temperature-dependent properties

General format:

<Property> types may be:

Component Temperature Dependent Special Properties

Note: If data or index values are not supplied, the kinematic viscosity is computed using the Twu method

Component Structural Data for UNIFAC (Optional - Section 18)

HVTB i, value/...

HLTB i, value/...

HLTM i, value/...

FORMATION(V or L or S, unit, M or WT) i, enthalpy, Gibbs/...

VANDERWAALS i, area, volume/...

<Property> (phase, tunit, propunit, M or WT)CORRELATION= icorr,LN or LOG or EXPFAC=ipos,DATA= i, tmax, tmin, C1, ..., C8 /...orTABULAR= t1, t2, ....,/i, p1, p2, ..., /...

VP(L or S, propunit, tunit),

ENTHALPY(I or L or S, propunit, tunit, M or WT),

CP(propunit, tunit, M or WT)

LATENT( propunit, tunit, M or WT),

DENSITY(L or S, propunit, tunit, M or WT),

VISCOSITY(V or L, propunit, tunit),

CONDUCTIVITY(V or L, propunit, tunit),

SURFACE(L, propunit, tunit)

KVIS(M or WT or LV) {GAMMA=value, REFINDEX=value, REFVALUE(kvisunit)=value,}

DATA(tunit, kvisunit) t1, t2, /i, p1, p2, /... ,

INDEX(tunit) t1, t2, /i, p1, p2, /...

STRUCTURE i, igroup(n)/...

GROUP igroup, Qj, Rj



Chapter 8 Thermodynamic Data Summary

About This Chapter

This section provides an overview of the Thermodynamic Data Category. Detailed documentation, along with examples of common usage of all the thermodynamic features, is contained in a separate document, the SIMSCI Component and Thermodynamic Data Input Manual. Unless noted otherwise, sections referred in this chapter refers to volume 2 of the SIMSCI Component and Thermodynamic Data Input Manual.

Heading Statement (required)

The METHOD Statement (required)

Selecting a Predefined System of Methods

THERMODYNAMIC DATA

METHOD SYSTEM(VLE or VLLE)= option,{KVALUE(SLE)= option}, {L1KEY= i and L2KEY= j},{KVALUE(VLE or LLE or VLLE)=option,ENTHALPY=option, DENSITY=option, ENTROPY=option}, {RVPMETHOD}, {TVPMETHOD}{PHI= option}, {HENRY},{PROPERTY(qualifier)=method}, {SET=setid, DEFAULT}orTRANSPORT= NONE TRANSPORT= PURE or PETRO or TRAPP or TACITE or U1 or U2 or U3 or U4 or U5

PIPEPHASE Keyword Manual May 2009 8-1

Selecting Individual Methods

METHOD SET= setid, {DEFAULT},KVALUE(VLE)= option, {KVALUE(SLE)=option},{KVALUE(LLE)= option}, {L1KEY= i and L2KEY= j},{PHI= option}, {HENRY},

or

KVALUE(VLLE)= option, {L1KEY= i and L2KEY= j},{KVALUE(SLE)= option}, {PHI= option}, {HENRY},ENTHALPY(VL)= option

or ENTHALPY(V)= option and ENTHALPY(L)= option,{RVPMETHOD}, {TVPMETHOD}, PROPERTY=method},

or DENSITY(VL)= optionDENSITY(V)= option and DENSITY(L)= option,

or ENTROPY(VL)= NONEENTROPY(V)= option, ENTROPY(L)= option,

TRANSPORT= NONE or TRANSPORT=PURE or PETRO or TRAPP or TACITE or U1 or U2 or U3 or U4 or U5

or

VISCOSITY(VL)= NONE or VISCOSITY(VL)= PURE orPETRO or TRAPP or U1 or U2 or U3 or U4 or U5

or

VISCOSITY(V)= option, VISCOSITY(L)= option,

and/or

CONDUCTIVITY(VL)= NONE or CONDUCTIVITY(VL)=PURE orPETRO or TRAPP or U1 or U2 or U3 or U4 or U5

or CONDUCTIVITY(V)= option, or CONDUCTIVITY(L)= option

and/or

SURFACE= NONE or SURFACE= PURE orPETRO or U1 or U2 or U3 orU4 or U5

DIFFUSIVITY (L) = NONE or DIFFUSIVITY(L)=WILKEor DIFDATA

8-2 May 2009 Thermodynamic Data Summary

Method-Specific Water Handling Options (optional - Section 2.1.6)

Property Statements (optional)

Vapor-Liquid Equilibrium Options (optional)

Note: Only the STANDARD option is available for molar liquid volume (MOLVOL) calculations when the WILSON K-value method is selected.

Liquid-Liquid Equilibrium Options (optional)

Solid-Liquid Equilibrium Options (optional - Section 2.7)

Diffusivity Options (optional - Section 2.7.3)

Vapor Fugacity Options (optional - Sections 2.5.12, 2.5.13)

WATER DECANT= ON or OFF, {GPSA},SOLUBILITY= SIMSCI or KEROSENE, or EOSPROPERTY= SATURATED or STEAM

KVALUE(VLE) POYNTING= OFF or ON,MOLVOL= STANDARD or RACKETT or RCK2 or LIBRARY,BANK= SIMSCI or ALCOHOL or GLYCOL or NONE or bankid,FILL= NONE or UNIFAC or UFT1 or REGULAR or FLORY,AZEOTROPE= SIMSCI or NONE or bankid {WRITE= fileid}ALPHA= ACENTRIC or SIMSCI or bankid (default depends on method)

<optional data statements> ...

KVALUE(LLE) BANK= SIMSCI or ALCOHOL or GLYCOL or NONE or bankid,FILL= NONE or UNIFAC or UFT1 or REGULAR or FLORY,AZEOTROPE= SIMSCI or NONE or bankid {WRITE= fileid}ALPHA= ACENTRIC or SIMSCI or bankid(default depends on method)


KVALUE(SLE) FILL=VANTHOFF or ONE or FREE

SOLUTE i, j, .....

SOLDATA(tunit) i, l, c1, c2, c3, / ...

DIFFUSIVITY(L)

DIFDATA (tunit) i, j, c1, c2, c3 / ...

PHI BANK=SIMSCI or NONE or bankid, ALPHA=ACENTRIC or SIMSCI or bankid



Henry’s Law Options (optional - Section 2.5.11)

Density Options (optional)

Enthalpy Options (optional)

Entropy Options (optional)

HENRY BANK= SIMSCI or NONE or bankidSOLUTEHENDATA(punit, tunit)

i, j, ...i, l, c1, c2, c3, c4 / ...

DENSITY(VL) BANK= SIMSCI or NONE or bankid, ALPHA= ACENTRIC or SIMSCI or bankid

or

DENSITY(V)

BANK= SIMSCI or NONE or bankid, ALPHA=ACENTRIC or SIMSCI or bankid

and/or

DENSITY(L) BANK= SIMSCI or NONE or bankid, ALPHA= ACENTRIC or SIMSCI or bankid


ENTHALPY(VL) BANK= SIMSCI or NONE or bankid, ALPHA=ACENTRIC or SIMSCI or bankidHMIX= IDEAL or GAMMA or RK1 or RK2

or

ENTHALPY(V) BANK= SIMSCI or NONE or bankid, ALPHA=ACENTRIC or SIMSCI or bankid

and/or

ENTHALPY(L) BANK= SIMSCI or NONE or bankid, ALPHA=ACENTRIC or SIMSCI or bankidHMIX= NONE or GAMMA or RK1 or RK2


ENTROPY(VL) BANK= SIMSCI or NONE or bankid, ALPHA=ACENTRIC or SIMSCI or bankid,

or

ENTROPY(V) BANK= SIMSCI or NONE or bankid, ALPHA= ACENTRIC or SIMSCI or bankid,

and/or

ENTROPY(L) BANK= SIMSCI or NONE or bankid, ALPHA= ACENTRIC or SIMSCI or bankid



User-Supplied K-value Data (optional - Section 2.3.12)

(Use with KVALUE statements)

Binary Interaction Data (optional)

(Use with KVALUE, PHI, DENSITY, ENTHALPY, or ENTROPY statements)

BWRS Equation Of State Data (optional - Section 2.4.6)

HEXAMER Equation of State Data (optional - Section 2.4.7)

LKP Equation Of State Data (optional - Section 2.4.8)

Hayden-O’Connell Data (optional - Section 2.5.12)

(For vapor fugacity, vapor density, vapor enthalpy, and vapor entropy)

Truncated Virial Data (optional - Section 2.5.13)

(For vapor fugacity)

IDIMER Data (optional - Section 2.5.14)

(For vapor fugacity, vapor density, vapor enthalpy and vapor entropy)

Redlich-Kister Excess Properties Data (optional - Section 2.5.15)

KVALUE(VLE or LLE)

KDATA CORR=icorr, LN or LOG or EXPFAC=ipos,PREF(punit)=valueDATA=i, tmax, tmin, c1, ...c8/ ...

or

KDATA TABU=t1, t2, .../ i, p1, p2, .../ ..., PREF(punit)=value

BWRS i, j, kij / ...

HEXA(K or R) i, j, kija, kjia, kijb, kjib, kijc, kjic, cij, cji / ...

LKP i, j, kij / ...

HOCV i, i, nii / i, j, nij / ...

TVIRIAL i, hi

IDIMER i, i, Aii, Bii / i, j, Aij, Bij / ...


(Currently for heat of mixing only)

Soave-Redlich-Kwong or Peng-Robinson Equation of State Interaction Parameters (optional - Section 2.4.1 to 2.4.3)

Liquid Phase Activity Binary Interaction Data (Section 2.5)

NRTL Data (optional - Section 2.5.1)

UNIQUAC Data (optional - Section 2.5.2)

RK1(K or KCAL or KJ) i, j, aij, bij, cij, dij, eij, fij, gij, hij, / ...

or

RK2(K or KCAL or KJ) , j, aij, bij, cij, dij, eij, fij, gij, hij, / ...

SRK(K or R) orPR(K or R)

i, j, kija, kijb, kijc / ...

or

SRKKD(K or R) i, j, kija, kijb, kijc / ...

or

SRKP(K or R) or PRP(K or R)

i, j, kija, kjia, kijb, kjib, kijc, kjic / ...

or

SRKM(K or R) orPRM(K or R)

i, j, kija, kjia, kijb, kjib, kijc, kjic, cij, cji / ...

or

SRKH(K or KCAL or KJ)orPRH(K or KCAL or KJ)

i, j, aij, bij, cij, aji, bji, cji, aij, bij / ...

or

SRKS(K or R) i, j, kija, kjia, kijb, kjib, kijc, kjic, cij, cji / ...

NRTL3(K or KCAL or KJ) i, j, bij, bji, aij / ...

or

NRTL(K or KCAL or KJ) i, j, aij, bij, aji, bji, aij / ...

or

NRTL6(K or KCAL or KJ) i, j, aij, bij, aji, bji, aij, bij / ...

or

NRTL8 (K or KCAL or KJ) , j, aij, bij, cij, aji, bji, cji aij, bij / ...

UNIQUAC(K or KCAL or KJ) i, j, aij, aji / ...

and/or

UNIQ4(K or KCAL or KJ) i, j, aij, aji, bij, bji / ...


Wilson Data (optional - Section 2.5.5)

Van Laar Data (optional - Section 2.5.6)

Margules Data (optional - Section 2.5.7)

Flory-Huggins Data (optional - Section 2.5.9)

Other Binary Data For Liquid Activity Methods (Section 2.5)

(For use with liquid activity methods, such as all forms of NRTL, UNIQUAC, Wilson, van Laar, and the Margules methods.)

Henry’s Law Data (optional - Section 2.5.11)

UNIFAC Group Contribution Data (optional - Section 2.5.3 to 2.5.4)

(For K-value calculations only)

UNIWAALS Modified Group Contribution Interaction Data (optional - Section 2.4.4)

WILSON(K or KCAL or KJ or NODIME)

i, j, aij, aji / ...

VANLAAR i, j, aij, aji / ...

MARGULES i, j, aij, aji, dij, / ...

FLORY i, j, / ...

AZEOTROPE(basis, punit, tunit) i, j, pres, temp, xi / ...

INFINITE(tunit) i, j, temp, , / ...

MUTUAL(basis, tunit) i, j, temp, , / ...

IDEAL i, j / ...

SOLUTE i, {j ...}

HENDATA(pres, temp) i, l, c1, c2, c3, c4 / ...

UNIFAC(K or KCAL or KJ)UNIFT1(K)

l, k, Alk, Akl / ...l, k, alk, akl, blk, bkl, clk, ckl / ...

or

UNIFT2(K) l, k, alk, akl, blk, bkl, clk, ckl / ...

or

UNIFT3(K) UNFV(K or KCAL or KJ)

l, k, alk, akl, blk, bkl, clk, ckl / ...l, k, alk, akl / ...

UNIFT1(K) l, k, alk, akl, blk, bkl, clk, ckl / ...

UNIFAC(K or KCAL or KJ) l, k, Alk, Akl / ...


Pure Component Alpha Formulations (optional - Section 2.4.5)

Special Property Methods (Used with PR, SRK, or UNIWAALS methods)

LS Data (optional - Section 2.8.2)

Method-Specific Pure Component Data (optional - Section 2.9)

PA01 or SA01 or VA01 PA02 or SA02 or VA02 PA03 or SA03 or VA03 PA04 or SA04 or VA04 PA05 or SA05 or VA05 PA06 or SA06 or VA06 PA07 or SA07 or VA07 PA08 or SA08 or VA08 PA09 or SA09 or VA09 PA10 or SA10 or VA10 PA11 or SA11 or VA11

i, c1 / ...i, c1, c2, c3 / ...i, c1, c2 / ...i, c1, c2 / ...i, c1, c2 / ...i, c1, c2, c3 / ...i, c1 / ...i, c1, c2, c3 / ...i, c1, c2, c3 / ...i, c1, c2, / ...i, c1, c2, / ...

Property(qualifier) {GAMMA=value, REFINDEX=value, REFVALUE(unit)=value},{NCFILL=ncfill}, {NCBLEND=ncblend}

DATA(unit)INDEX

i,datvalue/... i,indvalue/ ...

C(unit) i, value/...

PC(unit) i, value/...

VC(unit) i, value/...

ZC i, value/...

ACENTRIC i, value/...

NBP(unit) i, value/...

MOLVOL(unit) i, value/...

DIPOLE(unit) i, value/...

RADIUS(unit) i, value/...

SOLUPARA i, value/...

RACKETT i, value/...

WDELT i, value/...

PARACHOR i, value/...

PENELOUX(volunit) i, value/...


Appendix A Pressure Drop Correlations

Appendix Contents

Recommendations on Pressure Drop Correlations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2Single-Phase Methods. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2Two-Phase and Compositional Methods . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2

Table A-1: Single-Phase Pressure Drop Correlations . . . . . . . . . . . . . . . . . . . . . . . 3Weymouth . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3Moody (default) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3American Gas Association . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3Hazen-Williams . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3Moody (default) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3

Table A-2: Recommendations for Two-Phase Pressure Drop Correlations. . . . . . . 4Lockhart-Martinelli . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4Eaton. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4Dukler . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4Beggs & Brill . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4Mukherjee-Brill . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4

Table A-3: Experimental Information for Two-Phase Pressure Drop Correlations. 4Table A-4: Hybrid Models Summary. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5Table A-5: Correlations Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5Table A-6a: Two-Phase Pressure Correlations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6

Duns & Ross. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6Hagedorn & Brown . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6Angel-Welchon-Ross . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6

Table A-6b: Two-Phase Pressure Correlations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8Orkiszewski . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8Flanigan . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8

Table A-6c: Two-Phase Pressure Correlations . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10Beggs & Brill . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10Lockhart & Martinelli . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10Eaton. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10

Table A-6d: Two-Phase Pressure Correlations . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12

PIPEPHASE Keyword Manual A-1

Table A-6e: Two-Phase Pressure Correlations . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14General Guidelines on Correlation Selection . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 16

Recommendations on Pressure Drop Correlations

Single-Phase Methods

Single-phase pressure drop correlations (see Eqn. 6-19) tend to be based more on theory than experiment (with the exception of the American Gas Association method for single-phase gas, and the Hazen-Williams expression for single-phase liquid), and therefore fewer deviations can be expected for a majority of simulations between the methods. The default methods invoked will produce reasonable results in most cases and are therefore recommended for all such situations. In the case of high velocity gas flow, the Panhandle B and Weymouth methods both ignore the accelerational component of the pressure drop, and results should be inspected carefully and compared with those produced by using the Moody equation. If the flow is reported to be at or near to critical flow, then these correlations cannot be relied upon to be consistent in this region and the user should switch the fluid model to compositional and use one of the special high velocity correlations available (such as Beggs & Brill High Velocity), possibly in conjunction with the flare algorithm which can model physical occurrences such as critical pressure discontinuities.

Two-Phase and Compositional Methods

This appendix also contains a table that shows the merits for each of the major two-phase pressure drop correlations. Because of the heavy experimental basis of each of the two-phase methods, no single correlation can be recommended for all systems. Most piping systems contain topologies within which fluids flow in all directions and through a variety of valves and fittings. Therefore, if one were to select the appropriate correlation for each pipe run within a PIPEPHASE link, should the answer then be necessarily more accurate? The answer to this question is: probably not. The majority of the two-phase correlations available today have been produced to address much larger piping systems, typically transporting oil, gas and/or water, where the flow rates are relatively large, and much work has been performed on studying the effects of flow regime and other large topological changes on overall pressure drop. When this analysis is brought down to the level of refinery- or chemical plant-sized piping runs and typical simulations, these large-scale phenomena begin to lose meaning in translation, and the choice of pressure drop correlation, outside the arena of critical flow, tends to have correspondingly less impact on the results. With any two-phase flow system, the user is recommended to bracket the solution to the simulation by using two or more appropriate correlations. Bracketing means that the user may have more confidence in the true solution being between the values reported using the different correlations.

A-2 Pressure Drop Correlations

General Guidelines on Correlation Selection may be found at the end of this appendix.

Table A-1: Single-Phase Pressure Drop Correlations

Names and References

Friction Factor (dP/dL)f

Elevation Factor (dP/dL)e

Acceleration Factor (dP/dL)acc

Panhandle B

Weymouth

Moody (default)

American Gas Association106,107

Qg = gas flow rate, standard (ft3/

day) (SCFD)P1 = upstream pressure (psia)

P2 = downstream pressure (psia)

E = 5280 (coefficient)e = elevational change (ft)

d1 = inside diameter of the pipe

(in)

Z = gas compressibility factor at the flowing temperature and pressure (dimensionless)f = friction factor (dimensionless)

Tavg = average

flowing temperature of gas (OR)γg= gas specific

gravity (Air=1.00)For NRe 2000:

For NRe > 2000:

Hazen-Williams Q = bbl/day

E = Hazen-Williams coefficient; e = elevational change (ft); d1 = diameter (in)

dPdL-------

f

fv2

2gcd144---------------------=

f194------

pb

vTb------------

0.04=

dPdL-------

e

g singc144

------------------=dPdL-------

acc0=

dPdL-------

f

fv2

2gcd144---------------------=

f 1

71.6d0.33

----------------------=

dPdL-------

e

g singc144

------------------=dPdL-------

acc0=

dPdL-------

f

fv2

2gcd144---------------------=

1

f----- 1.74 2 2

d----- 18.7

NRe f---------------+

log–=

dPdL-------

e

g singc144

------------------= dPdL-------

acc

V1 V1 V2– 144gcL

---------------------------------=

Qg 38.77d15 2

f1 2

E52801 2

P12

P22

– ZavgTavg

gPavg2

---------------------------------------------- 0.0375e–

L---------------------------------------------------------------------------

0.5

=

NRe 1488vd

---------=f

NRe

16---------=

f f42

=

f4 min f2f3 =

f3 43.7 d--------- log=

f2 3.84NRe

1.4124f1--------------------- log=

f1 4NRe

f1--------- log 0.6–=

Q 15.2Ed12.63 P1 P2– 0.433e L–

LL-----------------------------------------------------------

0.54=


Table A-2: Recommendations for Two-Phase Pressure Drop Correlations

Table A-3: Experimental Information for Two-Phase Pressure Drop Correlations

Moody (default)

f from Moody diagram

Correlation Ref Correlation Recommendations*

Horizontal Flow

Lockhart-Martinelli 41 Widely used in the chemical industry. Applicable for annular and annular mist flow regimes if flow pattern is known a priori. Do not use for large pipes. Generally overpredicts pressure drop.

Eaton 42 Do not use for diameters < 2 inches. Do not use for very high or low liquid holdup. Underpredicts holdup for HL < 0.1. Works well for 0.1 < HL < 0.35.

Dukler 48 Good for horizontal flow. Tends to underpredict pressure drop and holdup. Recommended by API for wet gas lines.

Beggs & Brill 38 Use the no-slip option for low holdup. Underpredicts holdup. Most consistent and well-behaved correlation.

Inclined Flow

Mukherjee-Brill 44 Recommended for hilly terrain pipelines. New correlation based heavily on in-situ flow pattern. Only available model that calculates flow patterns for all flow configurations and uses this information to determine modeling technique.

* Note: Vertical upward flow correlations are not available in INPLANT -- most correlations were developed for large scale production applications.

Correlation Ref Date Basis Pipe Size(s) Fluids

Vertical Flow

Duns & Ross 33 1961 Lab. and field data wide range oil, gas, water

Angel-Welchon-Ross 37 1964 Field data Large-diameter tubing and annuli

gas, water

Hagedorn & Brown 34 1965 Lab and field data 1" – 4" oil, gas, water

Orkiszewski 35 1967 Review and modification of other methods

wide range oil, gas, water

Aziz & Govier 37 1972 Lab. and field data wide range oil, gas, water

Beggs & Brill 38 1973 Lab data 1", 1.5" gas, water

Gray 39 1974 Field data < 3.5" gas condensates

Horizontal Flow

Lockhart-Martinelli 41 1949 Lab. data 0.0586" - 1.1017"

Names and References

Friction Factor (dP/dL)f

Elevation Factor (dP/dL)e

Acceleration Factor (dP/dL)acc

dPdL-------

f

fv2

2gcd144---------------------=

NRe 1488vd

---------=

dPdL-------

e

g singc144

------------------=dPdL-------

acc0=


Table A-4: Hybrid Models Summary

Table A-5: Correlations Summary

Eaton 42 1966 Lab. and field data 2", 4"

Dukler 48 1969 Data and similarity analyses

wide range oil, gas, water

Inclined Flow

Mukherjee-Brill 44 1983 Lab data 1.5" kerosene, lube oil, gas

FCODE MAP HOLDUP PRESSURE DROP

FRICTION ELEVATION ACCELERATION

Dukler-EatonFlanigan (DE)

None EatonFlanigan

Dukler(Eaton Holdup)

Flanigan(Flanigan Holdup)

Eaton

Beggs & Brill Moody (BBM)

Beggs & Brill (BB)

Beggs & Brill

Beggs & Brill with Moody Friction Factor

Beggs & Brill Beggs & Brill

Beggs & BrillNo-slip (BBNS)

Beggs & Brill No-slip Holdup

Beggs & Brill with Moody Friction Factor

Beggs & Brill(No-slip Holdup)

Beggs & Brill

Dukler Flanigan (DF)

None Dukler Flanigan

Dukler (Dukler Holdup)

Flanigan (Flanigan Holdup)

No acceleration

Eaton Flanigan (EF)

None Eaton Flanigan

Eaton (Eaton Holdup)

Flanigan(Flanigan Holdup)

Mukherjee-BrillEaton

Mukherjee-Brill

*Eaton Mukherjee-Brill

Mukherjee-Brill

Mukherjee-Brill

Beggs & BrillMoody Dukler (BBMD)

Beggs & Brill *Dukler Beggs & BrillMoody Friction Factor


Beggs & BrillMoody Eaton (BBME)

Beggs & Brill *Eaton Beggs & BrillMoody Friction Factor


* Angle corrected by Beggs & Brill method


Beggs & Brill (BB) Beggs & Brill Beggs & Brill Beggs & Brill

Mukherjee-Brill (MB)

Mukherjee-Brill Mukherjee-Brill Mukherjee-Brill

Correlation Ref Date Basis Pipe Size(s) Fluids


Table A-6a: Two-Phase Pressure Correlations

Eaton (Eaton) None Eaton Eaton

Dukler (Duckler) None Dukler Dukler

Lockhart-Martinelli None Lockhart-Martinelli

Lockhart-Martinelli

Name Holdup(HL)

Duns & Ross Flow patterns from Duns & Ross flow pattern mapBubble flow, slug flow

Mist flow

Transition flow

Hagedorn & Brown

Angel-Welchon-Ross


Hl Vs Vm–Vm Vs– 2 4Vs Vsl+ +

2Vs-------------------------------------------------------------+=

Vs calculated from correlation

Hl l

Vsl

Vsl Vsg+----------------------= =

Hl A1 Hl slug

B1 Hl slug

+=

A1 f(dimensionless numbers),= 0 A1 1 B1 1 A1–=

Hl f (dimensionless numbers), calculated from correlation =

Hl l= (no-slip holdup)


Table A-6a: Duns & Ross33; Hagedorn & Brown34; Angel-Welchon-Ross37

Friction (dP/dL)f Elevation (dP/dL)e Acceleration (dP/dL)acc

Bubble and Slug Flow

Bubble, Slug and Mist Flow

Bubble and Slug Flow

Mist flow Mist flow

Transition Flow Transition Flow Transition Flow

dPdL-------

f

fmlVslVm

2gcd 144 -------------------------=

fm from correlation

dPdL-------

e

tpVslg sin

gc 144 ------------------------------=

tp lHl gHg+=

dPdL-------

acc0=

dPdL-------

f

fg Vsg2

2gcd 144 ---------------------------=

Vsg

Vsgd2

d – 2-------------------=

e = roughness from pipe and liquid film

f calculated from Moody diagram

dPdL-------

acc

VmVsgn

gcP 144 ----------------------

dPdL-------

T=

n ll 1 l– g+=

dPdL-------

f

A1dPdL-------

f slugB1

dPdL-------

f mist+

=dPdL-------

e

A1dPdL-------

e slugB1

dPdL-------

e mist+

=dPdL-------

acc

A1dPdL-------

acc slugB1

dPdL-------

acc mist+

=

dPdL-------

f

ftVm2

2gcd 144 ------------------------=

t

n2

s------=

s lHl gHg+=

s lHl gHg+=

NRe

1488nVmd

s-----------------------------=

dPdL-------

e

sg sin

gc 144 --------------------=

dPdL-------

acc

VmVsgn

gcP 144 ----------------------

dpdL------

T=

dPdL-------

f

fmlVslVm

2gcd 144 -------------------------=

dPdL-------

e

sg sin

gc 144 --------------------=

dPdL-------

acc0=


Table A-6b: Two-Phase Pressure Correlations

Name Holdup(HL)

Orkiszewski Flow patterns from Orkiszewski’s suggested flow pattern mapBubble Flow

Slug Flow

Mist Flow

Same as Duns & Ross

Transition Flow

Flanigan

Hl 1 12--- 1

Vm

Vs------- 1

Vm

Vs-------+

24

Vsg

Vs--------––+–= Vs 0.8ft s=

Hl

s g–

l g–-----------------=

s l Vsl Vb+ sVsg l+ +=

Vb f NRe =

NRe f Vb =

(calculation is iterative)

Hl A1 Hl slug

B1 Hl slug

+=

A1 f(dimensionless numbers),= 0 A1 B1 1 A1–=

Hl1

1 0.3264Vsg1.05

+---------------------------------------=


Table A-6b: Orkiszewski35; Flanigan40


Bubble flow

Bubble, Slug and Mist Flow

Bubble and Slug flow

Slug flow

Mist Flow Mist Flow

Same as Duns & Ross

Transition Flow Transition Flow

dPdL-------

f

fl

Vsl

Hl-------

2

2gcd 144 ------------------------=

dPdL-------

e

sg sin

gc 144 --------------------=

dPdL-------

a0=

dpdL------

f

fl

Vsl

Hl-------

2

2gcd 144 ------------------------=

dPdL-------

f

A1dPdL-------

f slugB1

dPdL-------

f mist+

=

dPdL-------

acc

VmVsgn

gcP 144 ----------------------

dPdL-------

T=

n ll 1 l– g+=

dPdL-------

f

A1dPdL-------

f slugB1

dPdL-------

f mist+

=dPdL-------

acc

A1dPdL-------

acc slugB1

dPdL-------

acc mist+

=


Table A-6c: Two-Phase Pressure Correlations

Name Holdup(HL)

Beggs & Brill Flow Pattern from Beggs and Brill Flow Pattern Map

TransitIon Flow

Lockhart & Martinelli HL = f(x), calculated from correlation

Eaton HL = f(dimensionless numbers), calculated from correlation

Hl

aLb

NFrc

--------- =

0= , 0=

0 , 1 C 1.8 sin 0.33 1.8 sin– +=

C 1 L– dLeNLVf

NFrg ln=

a,b,c,d,e,f,g = constants, f(flow pattern)

HL A4 HL seg

B4 HL int

+=


x

dpdL------

L

s

dpdL------

g

s---------------

12---

=dpdL------

L

s fLLV2

sL

2gcd 144 ------------------------= NRe,L 1488

LVsLd

L------------------=

dpdL------

g

s fLgV2

sg

2gcd 144 ------------------------= NRe,g 1488

gVsgd

L-----------------=


Table A-6c: Beggs & Brill38; Lockhart & Martinelli41; Eaton42


Segregated, Intermittent, Distributed Flow

fn from Moody diagram for smooth pipe

Transition Flow:

dpdL------

f

ftpsVm2

2gcd 144 -----------------------=

ftp

fn----- e

5=

NRe 1488nVmd

n----------------=

dpdL------

e

sg sin

gc 144 --------------------=

s LHL gHg+=

dpdL------

acc

VmVsgs

gcP 144 ---------------------- dp

dL------

T=

S y

a0– a1y a2y2

a4y4

––+-----------------------------------------------------------=

a0 0.0523= a1 3.182=

a2 0.8725= a4 0.01863=

S 2.2ey

1.2– ln= if 1 ey

1.2

yL

L2

------

ln=

dpdL------

fA4

dpdL------

f,segB4

dpdL------

f,int+=

dpdL------

f

g2 dp

dL------

g

sg

2 dpdL------ s

L+

2--------------------------------------------------=

g f X1NRe ,g = L f X1NRe,L =

dpdL------

e

sg sin

gc 144 --------------------=

s LHL gHg+=

dpdL------

acc0=

dpdL------

f

ftpnVm2

2gcd 144 -----------------------=

ftp calculated from correlation

dpdL------

e

sg sin

gc 144 --------------------=

s LHL gHg+=

dpdL------

acc

WLVL2

WgVg2

+

2gcqmL 144 -------------------------------------------=


Table A-6d: Two-Phase Pressure Correlations

Name Holdup(HL)

Aziz Flow pattern from Aziz et al. flow pattern mapBubble flow

Slug Flow

Mist Flow

Same as Duns & Ross

TransitIon Flow

Gray

Hl 1Vsg

Vbf--------–= Vbf 1.2Vm Vbs+=

Vbs 1.41Lg L g–

L2

--------------------------------

14---

=

Hl 1Vsg

Vbfsl-----------–= Vbfsl 1.2Vm Vbsl+=

Vbfsl Cdg L g–

L2

-----------------------------

12---

=

C = f(dimensionless numbers), calculated from correlation

HL A3 HL slug

B3 HL mist

+=


Hl 1 Hg–= Hg1 e

A1

–R 1+

-----------------=

A1

2.314 Nv 1 205Nd---------+

B1

–=

B1

0.0814 1 0.05554 1 0.730RR 1+

-----------------+ ln–=

RVsl

Vsg--------=

l

oqo 0.617wqw+

qo 0.617qw+----------------------------------------------= surface tension=

Nv

m2

Vsm2

gl l g– ------------------------------= Nd

g l g– D2

l--------------------------------=


Table A-6d: Aziz37; Gray39


Bubble Flow: Bubble and Slug Flow

Slug Flow:

Mist Flow Mist Flow

Same as Duns & Ross

Transition Flow Transition Flow

dPdL-------

f

fsVm2

2gcd 144 ------------------------=


NRe

1488lVmd

l----------------------------=

dPdL-------

e

sg sin

gc 144 --------------------=

s lHl gHg+=

dPdL-------

acc0=

dpdL------

f

flVm2Hl

2gcd 144 ------------------------= NRe

1488lVmd

l----------------------------=

dpdL------

acc

VmVsgs

gcP 144 ---------------------- dp

dL------

T=

dpdL------

fA4

dpdL------

f slug,B4

dpdL------

f mist,+=

dPdL-------

aA1

dPdL-------

a slug,B1

dPdL-------

a mist,+=

dpdL------

f

ftpsVm2

2gcd 144 ------------------------= NRe

1488nVmd

n-----------------------------=

dPdL-------

e

sg sin

gc 144 --------------------=

s lHl gHg+=

dpdL------

acc

VmVsgs

gcP 144 ---------------------- dp

dL------

T=


Table A-6e: Two-Phase Pressure Correlations

Name Holdup(HL)

Dukler HL = calculated from correlation iteratively

Mukherjee & Brill Flow pattern from Mukherjee and Brill flow pattern map

p

< 0 – Bubble, Slug, Mist flow

< 0 – Stratified flow

< 0 – All flow patterns

HL f L2

NRek NRek f HL = =

NRe 1488kVmd

n----------------= k

LL2

HL------------

gg2

Hg------------+=

Hl

aLb

NFrc

--------- =

HL eH2= H2 H1

NGV0.371771

NLV0.393952

---------------------=

H1 0.51664 0.789805 sin+– 0.551627sin2 15.519214NL2

+ +=

HL eH2= H2 H1

NGV0.079951

NLV0.504887

---------------------=

H1 1.330282 4.808139 sin+– 4.171584sin2 56.262268NL2

+ +=

HL eH2= H2 H1

NGV0.475686

NLV0.288657

---------------------=

H1 0.380113 0.129875 sin+– 0.119788sin2 2.343227NL2

+ +=


Table A-6e: Dukler48; Mukherjee & Brill44


Stratified Flow

Bubble, Slug Flow

Mist Flow

dpdL------

f

ftpkVm2

2gcd144 --------------------------=

ffn---- 1

y

a0 a1y a2y2

+– a3y3

– a4y4

+------------------------------------------------------------------------+=

a0 1.261= a1 0.478=

a2 0.444= a3 0.094=

a4 0.0084=

y L ln–=

fn 0.0056 0.5NRek+=

dpdL------

e

sg sin

gc 144 --------------------=

s LHL gHg+=dpdL------

acc

gVeg

2

Hg--------------

LVsL2

HL---------------+

gcL 144 ----------------------------------------------=

dpdL------

f

fgVg2

2gcdh 144 -------------------------=

NRe 1488gVgdh

g------------------=

dh hydraulic diameter of the pipe=

dpdL------

e

sg sin

gc 144 --------------------=

s LHL gHg+=

s g for stratified flow=

dpdL------

acc

VmVsgs

gcP 144 ---------------------- dp

dL------

T=

dpdL------

f

fmVm2

2gcd 144 -----------------------=

NRe 1488nVmd

g----------------=

dpdL------

f

ffrgVg2

2gcd 144 -----------------------=

NRe 1488nVmd

n----------------=

ffr calculated from correlation



General Guidelines on Correlation Selection

• For gas-dominated two-phase pipe runs with sub-critical flow:

Use the Dukler-Eaton correlation, and for cases with very low liquid loadings (less than 10 bbl/MMSCF, or 0.056 m3 /1000 sm3) bracket with the Beggs, Brill & Moody correlation. Mukherjee-Brill is better for 0.1< HL< 0.35.

• For single-phase liquid and liquid-dominated fluid lines, like crude oil and its prod-ucts and water:

Use the Beggs, Brill and Moody correlation.

• For dense phase gas pipelines, such as CO2 or NH3:

Use the Beggs, Brill and Moody correlation.

• For downward flowing pipes containing two-phase fluids or steam:

Use the Beggs & Brill No-Slip correlation.

• For all steam piping, except downward flowing pipes (as above):

Use the Beggs, Brill & Moody correlation.

• For high velocity and critical flow systems:

Use the high velocity modifications to the standard Beggs & Brill, and Beggs, Brill & Moody correlations.


Appendix B Glossary

Glossary of Frequently Used Terms

This section lists the meanings of frequently used terms in the INPLANT application.

Compressibility Generally only of importance in gas phases, this term refers to the gas deviation from ideal behavior.

Critical Flow Also referred to as sonic or limiting flow for single phase fluids. This term refers to the maximum speed of a fluid as being that of the speed of sound in the local fluid medium for single phase fluids. For multiphase fluids, critical and sonic flow are not equal, and critical flow becomes a practical quan-tity corresponding to a maximum mass flux.

Device This term describes any item of process equipment, pipe or fitting through which fluid is able to flow. A link comprises one or more devices.

Discontinuity In the context of critical flow, a pressure discontinuity occurs in a pipe section or device when critical flow has been achieved. Under these conditions the fluid velocity cannot increase and so the corresponding pressure cannot decrease until downstream conditions dictate otherwise. Critical dis-continuities by nature can only be sustained over short dis-tances, and the energy associated with the discontinuity is normally dissipated in the form of a shock wave.

Enthalpy This term refers to the heat content of a fluid. This value is related to the fluid temperature, pressure and composition and is used in pipe devices for heat balance calculations.

PIPEPHASE Keyword Manual B-1

Equivalent Length (Also known as K-multiplier) This term is used for specifying the pressure drop over a valve or fitting in terms of an equiva-lent number of pipe diameters. The equivalent length (in pipe diameters) is equal to L/d.

Equation-of-State This term describes an equation which relates pressure, volume, and temperature for a fluid. The ideal gas law is one such exam-ple, and modern cubic equations-of-state such as SRK are able to predict multiphase mixture behavior.

Equipment This phrase refers to devices which are typically described as process equipment, such as pumps, compressors, heaters, etc.

Flow Pattern In INPLANT, available flow patterns depicted on the Taitel-Dukler-Barnea flow map are intermittent, annular, dispersed bubble, stratified wavy and stratified smooth flows.

Flow Pattern Map This term typically describes a graphical representation of superficial liquid velocity versus superficial gas velocity. Each flow regime is marked on different segments on the graph.

Flow Regime This phrase is used to describe either turbulent or laminar flow. This term is often used interchangeably with Flow Pattern.

Fluid This term defines a single-phase or multi-phase group of com-ponents which are able to flow within a piping configuration.

Fortunati Model The Fortunati Model57 describes a method for the determination of critical flow in two-phase systems. This method arose from work on multiphase critical flow through chokes.

Friction Factor This term refers to the relative importance of wall shear stress to the total losses. The friction factor is generally related to the Reynolds number and to the ratio of wall roughness to the inter-nal pipe diameter.

Heat Transfer Coefficient

This term describes the rate of heat transfer from one medium to another medium per unit heat transfer area per degree of tem-perature. The media may be fluid flowing inside a pipe transfer-ring heat to the pipe wall medium. Heat transfer coefficients are generally complex empirical correlations, and are related to a number of dimensionless numbers, including the Reynolds number. The individual heat transfer coefficients may be com-bined to produce the overall heat transfer coefficient,

B-2 Glossary

Heat Transfer Resistance

Is the reciprocal of the heat transfer coefficient,

Internal Energy This describes the energy possessed by a fluid by virtue of its existence at a certain temperature (for an ideal gas) and pressure (for a real gas). Only differences in internal energy are of use in analysis, and then only in deriving other functions such as enthalpy, heat capacity at constant volume (Cv), etc.

Interval Halving This phrase refers to a network method solution technique when flow reversals are detected in loop configurations, but where flow reversals during the solution procedure have been disal-lowed by the user.

Junction This term describes a node which connects two or more links together.

K-factor (Also known as resistance coefficient.) This term refers to the number of velocity heads equivalent to the frictional pressure drop over a valve or fitting. The K-factor is numerically equal to fL/d.

K-multiplier See Equivalent Length.

Kinetic Energy This term refers to the energy possessed by a fluid by virtue of its motion. Kinetic energy is related to the mass and velocity of the fluid.

Laminar Flow Also known as Streamline Flow. This term refers to single phase fluid flow where the value of the Reynolds number is less than 3000 (user-definable value).

Link This is the term used to describe the serial string of devices which appear between any two nodes. The series of devices are ordered in the direction of flow as specified by the user.

Liquid Holdup This term is defined as the fraction of a pipe’s cross-sectional area which is occupied by liquid. Holdup is used extensively in two-phase fluid flow analyses, including the determination of flow regime and in the calculation of two-phase physical prop-erties such as density and viscosity.

Loading Refers to the fluid flow rate arising from a flare relief depressur-izing source.

Loop This phrase refers to a particular configuration of piping net-work where two or more junctions join together to form a loop.


Marching Algorithm This is a term used to describe the manner by which the device calculations are solved by INPLANT. The solution proceeds in a sequential manner, where the outlet conditions of a fluid from one calculation segment are used as the inlet conditions for the next segment. In networks, INPLANT always works in the for-ward direction (i.e., in the link FROM=, TO= definition) when conducting pressure drop calculations.

Mixing Rule This term refers to the mathematical method used to combine properties into a single value for subsequent use in a correlation. An equation-of-state uses a mixing rule in combining compo-nent properties in order to predict overall fluid phase behavior. However, a non-compositional viscosity method may use a mixing rule in order to combine overall phase viscosities in order to generate a single value for use in the relevant pressure drop correlations.

Moody Pulse Model The Moody Pulse Model4 is a method for the determination of critical flow in two-phase systems. In this method the critical mass flux is ascertained for both homogeneous and separated flow patterns

Network Diagram This term refers to a diagram of the structure of an INPLANT network which contains only the nodes and links, with their labels, together with flow direction arrows and major devices. This diagram is essential for diagnosing any convergence prob-lems and as accompanying documentation to any network simu-lation.

Network Method This is a simulation type which normally involves more than one source and/or more than one sink. The Network Method is the algorithm invoked to solve these configurations, and may operate also on problems referred to as single link.

No-Slip This term is used to describe two-phase fluid flow where both phases are traveling at the same velocity.

Node This phrase refers to a fluid source, sink or junction.

Potential Energy This term is the energy possessed by a fluid by virtue of its posi-tion. Potential energy is related to the mass and elevation of the fluid relative to a reference datum.

Pressure Traverse Is a phrase used to describe the pressure drop calculation across a calculation segment in the forward direction.

B-4 Glossary

Resistance Coefficient See K-factor.

Reynolds Number This is a dimensionless number which represents the ratio of a fluid’s inertia forces to its viscous forces. This number is used extensively in pressure drop analyses and correlations.

Roughness This term describes the absolute value of the mean size of roughness on the inside of a section of pipe. This factor is used in correlations for the prediction of friction factors.

Segment A calculation segment in INPLANT refers to that subdivision of pipe over which iterative heat and mass balances are performed.

Shear Stress This term refers to the frictional force working at the pipe wall against the direction of fluid flow.

Shock Wave This term describes a fast and violent dissipation of energy associated with the change from a critical flow condition to that of subcritical flow.

Shut-in This phrase refers to a source or sink in a network which has either zero flow during (or at) solution, or has become its oppo-site number by virtue of flow reversal in the connecting link. This source or sink is subsequently eliminated from the solution procedure together with corresponding feed link(s).

Single Link Method This term describes a simulation type which involves only one fluid source, one sink, and one series of devices.

Sink This is a node from where fluid leaves, or is rejected from, the system.

Slip This term is used to describe a two-phase fluid flow phenome-non where one phase travels at a different speed than the other. The faster phase is then said to “slip” past the slower phase. Positive slip refers to situations where the gas phase is travel-ling faster than the liquid, and negative slip refers to the reverse situation.

Sonic Flow See Critical Flow.

Source This is a node from where a fluid is introduced into the system.

Spur Link In the network method, this term describes a sink link which has its flow rate fixed by the user, and can consequently be decou-pled from the main iterative solution matrix.


Steady State A condition which does not change with time. Steady state flow therefore refers to a condition where all aspects of the fluid flow, from physical properties to flow regime, do not change with time.

Streamline Flow See Laminar Flow.

Superficial Velocity This term is defined as the velocity of a particular phase of fluid in a pipe if it alone occupied the entire area for flow.

Turbulent Flow This refers to fluid flow where the value of the Reynolds num-ber is greater than 3000 (a user-definable value) in INPLANT.

Work This term refers to energy applied to, or taken from, a system by means other than heat input or output. Shaft work refers to the work done on or by a flowing fluid through a mechanical device which uses a shaft. Examples include a pump (for shaft work done on the fluid) or a turbine (for work done by the fluid).

B-6 Glossary

Appendix CReferences

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Y. Taitel, D. Barnea & A.E. Dukler: “Modeling Flow Pattern Transitions for Steady Upward Gas-Liquid Flow in Vertical Tubes,” AIChE Journal Vol. 26, No. 3, May. 1980, pages 345-354.

D. Barnea, Y. Taitel & O. Shoham: “Flow Pattern Transition for Vertical Downward Two-Phase Flow,” Chemical Eng. Science, Vol. 37, No. 5, 1982, page 741-744.

D. Barnea, Y. Taitel & O. Shoham: “Flow Pattern Transition for Downward Inclined Two-Phase Flow Horizontal to Vertical,” Chemical Eng. Science, Vol. 37, No. 5, 1982, page 735-740.

4. Moody, F.J.: “A Pressure Pulse Model for Two-Phase Critical Flow and Sonic Velocity,” Journal of Heat Transfer, Aug. 1969, Transactions of the ASME.

5. API Recommended Practice 520: “Recommended Practice for the Design and Installation of Pressure-Relieving Systems in Refineries: Part I - Sizing and Selec-tion,” Sixth Edition (1993).

6. Leung, J.: “Size Safety Relief Valves for Flashing Liquids,” Chemical Eng. Progress, Feb. 1992, pages 70-75.

7. Standing, M.B. and D.L. Katz: Density of Natural Gases Trans. AIME, 1962, 140.

Yarborough, L. and K.R. Hall: “How to Solve Equations of State for Z Factors,” Oil and Gas Journal.

PIPEPHASE Keyword Manual C-1

8. Lee, A.L. et al: ‘‘The Viscosity of Natural Gases,’’ Trans AIME, (1966) 997.

9. Katz, D.L. & Carr, N.L. et al: “Viscosity of Hydrocarbon Gases Under Pressure,” Trans AIME (1954) page 264.

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Chew, J. and C.A. Conally, “A Viscosity Correlation for Gas Saturated Crude Oils,” Trans AIME (1951), 223.

12. 1967 ASME Steam Tables. 345 East 47th Street, New York, NY 10017.

13. SIMSCI Component Library.

14. Reid, Prausnitz and Sherwood: “The Properties of Gases and Liquids,” McGraw-Hill, 1977.

Letsou, A., and L.I. Stiel, A.I.Ch.E. J., 19, p. 409 (1973).

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Thomas, J., Chem. Soc., Part II, pp. 573-579 (1946).

Gunn, R.D. and T. Yamada, A.I.Ch.E. J., 17, p. 1341 (1971).

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Riedel, Chem. Ing. Tech., 26, p. 83 (1954).

Kendall and Monroe, J. Am. Chem. Soc., 39, p. 1787 (1917).

15. Thodos, G. and Yoon, A.I.Ch.E. J., 16, p. 300 (1970).

Dean, D.G. and L.S. Stiel, A.I.Ch.E. J., 11 p. 526 (1965).

Herning and Zipperer, Gas-U. Wasserfach, 79, p. 69 (1936).

16. Leland, T.W., J.S. Robinson, and G.A. Suther, Trans Farad. Soc., 64, 1447, 1968.

17. API Technical Data Book, 5th Ed. (1978).

Reid, Prausnitz and Sherwood: “The Properties of Gases and Liquids,” McGraw-Hill, p. 524 (1977).

Riedel, L., Chem. Ing. Tech., 21, p. 349 (1949).

18. Roy, D. and G. Thodos, I & E.C. Fund., 9, p. 71 (1970).

Stiel, L. I. and G. Thodos, A.I.Ch.E. J., 10 p. 26 (1964).

C-2 References

Reid, Prausnitz and Sherwood: “The Properties of Gases and Liquids,” McGraw-Hill, p. 481-504 (1977).

Perry, R.H. and C.H. Chilton: “Chemical Engineers Handbook,” McGraw-Hill, p. 3-244 (1973).

19. API Technical Data Book - Petroleum Refining, 5th Revision (1978), pp. 6-45, 6-46.

20. Soave, G., Chem Engr. Sci., 27, No. 6, p. 1197 (1972). Erbar, J.H., GPA K & MOD II Program (August 1974).

Reid, Prausnitz, and Sherwood, The Properties of Gases and Liquids, 3rd Edition (1977).

21. Peng, D.Y., and D.B. Robinson: “A New Two Constant Equation of State,” I. & E.C. Fund., 51, pp. 59-64 (1976).

22. Kesler, M.G. and B.I. Lee, A.I.Ch.E. J., 21, No. 3, p. 510 (1975).

Kesler, M.G. and B.I. Lee, Hydrocarbon Proc., p. 153, March 1976.

Tarakad, R.R. and Ronald Danner, A.I.Ch.E. J., 22, No. 2, pp. 409-411, March 1976.

API Technical Data Book - Petroleum Refining, 3rd Edition, pp. 2-1 to 7-4.

23. Lee, B.I., M.G. Kesler, A.I.Ch.E. J., 21 (3), 510 (1975).

Leland, T.W., W.H. Mueller, I. & E.C., 51 (4), 597, (1959).

Pitzer, K.S., G. O. Hultgren, J.Am.Chem.Soc., 80, 4793 (1958).

Plocker, U., Helmut Knapp, John Prausnitz, I. & E.C. Proc.Des.Dev., Vol. 17, No. 3 (1978).

Prausnitz, J.M., R.D. Gunn, A.I.Ch.E.J., 4, 430, 494 (1958).

24. Simulation Sciences Inc., 1983: “The Twu Method for Prediction of Critical Proper-ties and Molecular Weights for Petroleum and Coal Tar Liquids,” Technical Bulletin #27.

Starling, K.E., J.E. Powers, I. & E.C. Fund., 9,531 (1970).

Starling, K.E., L.L. Lee, C.H. Twu, K.C. Mo, 1978: “Self Consistent Correlation of Thermodynamic and Transport Properties”, Thesis, Gas Research Institute and A.G.A. School of Chemical Engineering, University of Oklahoma.

Twu, C.H.: “Prediction of Thermodynamic Properties of Normal Paraffins Using only Normal Boiling Point,” Fluid Phase Equilibria, 11 (1983), 65-81, Elsevier Sci-ence Publishers, B. V., Amsterdam.

Twu, C.H.: “Boiling Point as a Third Parameter for Use in a Generalized Equation of State,” Fluid Phase Equilibria, 13, (1983), 189-194, Elsevier Science Publishers.


Twu, C.H.: “An Internally Consistent Correlation for Predicting the Critical Proper-ties and Molecular Weights of Petroleum and Coal Tar Liquids,” Fluid Phase Equi-libria, 00, (1984), FLU00628, Elsevier Science Publishers.

25. Kesler, M.G. and B. I. Lee, A.I.Ch.E. Journal, Volume 21, No. 3, pp. 510-527, May 1975.

Kesler M.G. and B.I. Lee, Hydrocarbon Processing, March 1976, p. 153.

26. Twu, Chorng H.: “An Internally Consistent Correlation for Predicting Critical Prop-erties and Molecular Weight of Petroleum and Coal Tar Liquids,” 1983 submitted for publication.

27. Grayson, H.G., and G.W. Streed: “Vapor Liquid Equilibria for High Temperature, High Pressure Systems,” 6th World Petroleum Congress, West Germany, June (1963).

28. Redlich, O., and J.N.W. Kwong, Chem. Rev., 44,233 (1949).

29. Ibid, Procedure 7h2.1, pp. 7-201 to 7-202.

Stewart, Burkhart and Voo: “Prediction of Pseudo-critical Constants for Mixtures,” A.I.Ch.E Meeting, Kansas City, May 18, 1959.

30. Johnson and Grayson, Petroleum Refiner, 40, No. 2, p. 123, (1961).

31. Chao, K.D. and J.D.Seader, A.I.Ch.E. Journal, pp. 598-605, December 1961.

Hildebrand, H.H. and R.L. Scott: “The Solubility of Nonelectrolytes,” 3rd edition, Reinhold, New York(1950).

Redlich, O., and J.N.W. Kwong, Chem. Rev., 44,233 (1949).

32. Bingham & Jackson Bureau of Standards Bulletin 14,75 (1918) referenced in Lange’s Handbook of Chemistry and Perry’s 4th edition.

33. Duns, H., Jr. and N.C.J. Ros: “Vertical Flow of Gas and Liquid Mixtures in Wells,” Proc., 6th World Pet. Congress (1963), 451.

34. Hagedorn, A.R. and K.E. Brown: “Experimental Study of Pressure Gradients Occurring During Continuous Two-Phase Flow in Small-Diameter Vertical Con-duits,” J. Pet. Tech. (April, 1965) 475-484.

35. Orkiszewski, J.: “Predicting Two-Phase Pressure Drops in Vertical Pipes,” J. Pet. Tech. (June, 1967) 829-838.

36. Angel, R.R. and J.K. Welchon: “Low Ratio Gas-Lift Correlation for Casing-Tubing Annuli and Large-Diameter Tubing,” Drill. and Prod. Prac., API (1964) 100.

37. Aziz, K., G.W. Govier, and M. Fogarasi: “Pressure Drop in Wells Producing Oil and Gas,” J. Cdn. Pet. Tech. (July-Sept., 1972) 38-48.

38. Beggs, H.D.: “An Experimental Study of Two-Phase Flow in Inclined Pipes,” Ph.D. Dissertation, the U. of Tulsa (1972).

C-4 References

39. Gray, H.E.: “Vertical Flow Correlation in Gas Wells,” in User Manual for API 14B, Subsurface Controlled Safety Valve Sizing Computer Program, App. B (June 1974).

40. Flanigan, O.: “Effect of Uphill Flow on Pressure Drop in Design of Two-Phase Gathering Systems,” Oil and Gas Jour. (March 10, 1958) 56.

41. Lockhart, R.W. and R.C. Martinelli: “Proposed Correlation of Data for Isothermal Two-Phase, Two Component Flow in Pipes,” Chem. Eng. Prog. (Jan. 1949) 45, 39.

42. Eaton, B.A.: “The Prediction of Flow Patterns, Liquid Holdup and Pressure Losses Occurring during Continuous Two-Phase Flow in Horizontal Pipelines,’’ Ph.D. The-sis, The U. of Texas (1966).

43. Steady-State Flow Computation Manual for Natural Gas Transmission Lines, Amer-ican Gas Association, New York (1964).

44. Mukherjee, H. K.: “An Experimental Study of Inclined Two Phase Flow”, Ph.D. dis-sertation, University of Tulsa, 1979.

45. Lawson, J. D. and J.P. Brill: “A Statistical Evaluation of Methods used to Predict Pressure Losses for Multiphase Flow in Vertical Oil Well Tubing”, SPE 4267 to be presented at 48th Annual SPE fall Meeting, Las Vegas, Nev.,Sept 30 -Oct. 3, 1973.

Vohra, I. R., J.R. Robinson,J.P. Brill: “Evaluation of Three New Methods for Pre-dicting Pressure Losses in Vertical Oil Well Tubing”, SPE 4689, presented at the 48th annual SPE Fall meeting, Las Vegas, Nev., 1973.

46. Browne, E.J.P.: “Practical Aspects of Predicting Errors in Two-Phase Pressure Loss Calculations”, SPE 5000, Presented at the 49th Annual SPE fall Meeting, Houston, Texas, 1974.

47. Degance, A.E. and R.W.Atherton: “Horizontal - Flow Correlations”, Chem. Eng. (July 13, 1970), 95.

48. Dukler, A.E., et al: “Gas-Liquid Flow in Pipelines, I. Research Results”, AGA-API Project NX -28 (May 1969).

49. Mandhane, J.M.,G.A.Gregory,K.Aziz: “Critical Evaluation of Holdup Prediction Methods For Gas-Liquid Flow in Horizontal Pipes”, SPE 5140, Presented at SPE Annual Fall Meeting, Houston, Texas, Oct. 1974.

50. Vohra, I.R., et al: “Comparison of Liquid Holdup Correlations For Gas-Liquid Flow in Horizontal Pipes”, SPE 4690, Presented at the SPE Annual Fall Meeting, Las Vegas, Nev., Oct. 1973.

51. Palmer, C.M.: “Evaluation of Inclined Pipe Two-Phase Liquid Holdup Correlations Using Experimental Data,” M.S. Thesis, The U. of Tulsa (1975).

52. Payne, G.A.: “Experimental Evaluation of Two-Phase Pressure Loss Correlations for Inclined Pipe,” M.S. Thesis, The U. of Tulsa (1975).

53. SIMSCI Steam Package from: Keenan, J.H. et al: “Thermodynamic Properties of Water Including Vapor, Liquid and Solid Phases,” John Wiley & Sons Inc.


54. Eaton, B.A.: “The Prediction of Flow Patterns, Liquid Holdup and Pressure Losses Occurring during Continuous Two-Phase Flow in Horizontal Pipelines,” Ph.D. The-sis, The U. of Texas (1966).

55. API Technical Data Book for Petroleum Refining (1980). Procedure 2B2.1

56. Twu, Chorng H.: “An Internally Consistent Correlation for Predicting Critical Prop-erties and Molecular Weight of Petroleum and Coal Tar Liquids,” 1983 submitted for publication.

57. Fortunati, F.: “Two-Phase Flow Through Wellhead Chokes,” SPE 3742, presented at SPE European Spring Meeting, Amsterdam, the Netherlands, May, 1972.

58. Hazen-Williams.

59. Crane Ltd.: “Flow of Fluids Through Valves, Fittings and Pipe.” Technical Paper No. 410M, 1988.

60. Barua, S., Sharma, Y., and Brosius, M.G.: “Two-phase flow model aids flare net-work design,’’ Oil & Gas Journal, Jan. 27 1992, pp. 90-94.

61. Blevins, Robert D.: “Applied Fluid Dynamics Handbook.” Van Nostrand Reinhold Company.

62. Fisher, H.G. et al: “Emergency Relief System Design Using DIERS Technology-Project Manual.” AIChE, 1992.

63. API Standard 526, “Flanged Steel Safety--Relief Valves,” Third Edition (1989).

64. Leung, J.C., “A Generalized Correlation for One-Component Homogeneous Equi-librium Flashing Choked Flow,” AIChE J., 1743--1746, October (1986).

65. Nazario, F.N. and J.C. Leung, “Sizing pressure relief valves in flashing two-phase service: an alternative procedure,” J. Loss Prev. Proc. Ind., 263-269, 5 (1992).

66. Simpson, L.L., “Estimate Two-Phase Flow in Safety Devices,” Chem. Eng., 98--102, August (1991).

67. Smith, J.M., and H.C. Van Ness, Introduction to Chemical Engineering Thermody-namics, 3rd edition, McGraw-Hill (1981).

68. API Recommended Practice 520: “Recommended Practice for the Design and Installation of Pressure-Relieving Systems in Refineries: Part II - Design,” Sixth Edition, (1993).

69. Lasater, J.A.: “Bubble Point Pressure Correlation,” Trans. AIME, 1958, 379.

70. Beggs, H.D. and Robinson,J.R.: “Estimating the Viscosity of Crude Oil Systems,” JPT (September 1975) 1140.

71. Glaso, O. “Generalized Pressure-Volume-Temperature Correlations,” JPT (May 1980) 785; Trans., AIME, 269.

72. Standing, M.B.: “A General Pressure-Volume-Temperature Correlation -- For Mix-tures of California Oils and Greases,” Drilling and Production Practice API (1947), 275.

C-6 References

73. Vazquez, A., M.E.: “Correlations for Fluid Physical Property Prediction,” M.S. The-sis, Tulsa University.

74. Ramey, H.J. Jr., “Wellbore Heat Transmission,” J. Pet. Tech., April 1962, 427-440.

75. Churchill, S.W., “Comprehensive Correlating Equations for Heat, Mass and Momentum Transfer in Fully-Developed Flow in Smooth Tubes,” Industrial & Engineering Chemistry Fundamentals, 1977, 16 (1), pp 109-115.

76. Churchill, S.W. (1977), “Comprehensive Correlating Equations for Heat, Mass, and Momentum Transfer in Fully Developed Flow in Smooth Tubes,” Ind. Eng. Chemis-try Fundamentals, Vol. 16, No. 1, pp. 109-115.

77. Ansari, A.M.: “A Comprehensive Mechanistic Model for Upward Two-Phase Flow,” MS Thesis, University of Tulsa (1988).

78. Taitel, Y., Barnea, D., and Dukler, A.E.: “Modelling Flow Pattern Transition for Steady Upward Gas-Liquid Flow in Vertical Tubes,” AIChE J. (1980), 26, 345- 354.

79. Barnea, D.: “A Unified Model for Predicting Flow-Pattern Transition for the Whole Range of Pipe Inclinations,” Int. J. Multiphase Flow (1987), 13, 1-12.

80. Caetano, E.F.: “Upward Vertical Two-Phase Flow Through an Annulus,” Ph.D. Dis-sertation, University of Tulsa (1986).

81. Fernandes, R.C., Semait, T., and Dukler, A.E.: “Hydrodynamic Model for Gas-Liq-uid Slug Flow in Vertical Tubes,” AICHE J., (1986), 29, 981-989.

82. Sylvester, N.D.: “A Mechanistic Model for Two-Phase Vertical Slug Flow in Pipes,” ASME J. Energy Resources Tech., (1987), 109, 206-213.

83. Xiao, J.J., Shoham, O., and Brill, J.P.: “A Comprehensive Mechanistic Model for Two-Phase Flow in Pipelines,” 65th Annual SPE Conference, New Orleans, Sep-tember 23-26, 1990.

84. Taitel, Y. and Dukler, A.E.: “A Model for Predicting Flow Regime Transitions in Horizontal and Near Horizontal Gas-Liquid Flow,” AIChE J., 22, No. 1, 47-55 (1980).

85. Andritsos, N. and Hanratty, T.J.: “Influence of Interfacial Waves in Stratified Gas-Liquid Flow,” AIChE J., 33, No. 3, 444-454 (1987).

86. Baker, A., Nielsen, K. and Gabb, A.: “Pressure Loss, Liquid Holdup Calculations Developed,” Oil & Gas J., 55-59 (March 14, 1988).

McLeod, W.R., Rhodes, D.F., and Day, J.J.: “Radiotracers in Gas-Liquid Transpor-tation Problems - A Field Case,” J.Pet.Tech., 939-947 (August, 1971).

87. Oliemans, R.V.A., Potts, B.F., and Trope, N.: “Modelling of Annular Dispersed Two-Phase Flow in Vertical Pipes,” Int. J. Multiphase Flow 12, No. 5, 711-732 (1986).

88. Taitel, Y. and Barnea, D.: “A Consistent Approach for calculating Pressure Drops in Inclined Slug Flows,” Chem. Eng. Sci. 45, No. 5, 1199-1206 (1990).


89. Pauchon, C., Dhulesia, H., Lopez, D., and Fabre, J.: “TACITE: A Comprehensive Mechanistic Model for Two-Phase Flow,” BHRG Conference on Multiphase Pro-duction, Cannes, June 16-19, 1993.

90. Andritsos, N. and Hanratty, T.J.: “Influence of Interfacial Waves in Stratified Gas-Liquid Flows,” AIChE J., Vol. 33, 444-454.

91. Nicklin, D.J., Wilkes, J.O, and Davidson, J.F.: “Two-Phase Flow in Vertical Tubes,” Trans. Inst. Chem. Engrs., Vol 40, 497-514.

92. Andreussi, P. and Bendiksen, K.: “An Investigation of Void Fraction in Liquid Slugs for Horizontal and Inclined Gas-Liquid Flow,” Int. J. Multiphase Flow, Vol 15, 2, 937-946.

93. Bendiksen, K.H., Malnes, D., Moe, R., and Nuland, S.: “The Dynamic Two-Fluid Model OLGA: Theory and Application,” SPE Production Eng., May 1991.

94. Pratts, Michael.:Thermal Recovery, SPE Monograph., Volume 7.

95. Barua, S.: “Computation of Heat Transfer in Wellbores in Single and Dual Comple-tions,” SPE 22868.

96. Perkins, Thomas K.: “Critical and Subcritical Flow of Multiphase Mixtures Through Chokes,” SPE 20633.

97. Ueda, Y., Samizo, N., and Shirakawa, S.: “Application of Production System Analy-sis to an Offshore Oil Field,” SPE 21419.

98. Jones, L., Blount, E., and Glaze, C.: “Use of Short Term Multiple Rate Flow Tests to Predict Performance of Wells having Turbulence,” SPE 6133, Oct. 3-6, 1976.

99. Hong, K. C.: “Two-Phase Flow Splitting at a Pipe Tee,” JPT, pp. 290, 1978.

100.Bergman, D. F., Tek, M. R., and Katz, D. L.: “Retrograde Condensation in Natural Gas Pipelines, “AGA Project PR 26-69, 191-199, 1975.

101.Johansen, S. E.: “Experimental Study of Gas-Liquid Flow in a Pipe Tee,” M.S. The-sis, Univ. of Tulsa, 1979.

102.Chien and Rubel: SPE 22764, Nov. 1992, SPEJ.

103.Oranje, L.: “Condensate Behavior in Gas Pipelines is Predictable,” Oil & Gas Jour-nal, 39-44, July 2, 1973.

104.Seeger et al: International Journal of Multiphase Flow, Vol. 12, No. 4, 575-585, 1986.

105.Ely, J.F., and H.J.M. Hanley: “Prediction of the Viscosity and Thermal Conductivity in Hydrocarbon Mixtures - Computer Program TRAPP,” Proceedings of 60th Annual Convention, Gas Processors Association, 1981.

106.Shashi Menon, E.: “Gas Pipeline Hydraulics”.

107.Hein, M.A.: “Pipeline Hydraulics and Heat Transfer Programs”.

C-8 References

Appendix D Default Values of Schedule Pipe Sizes

Steel Pipe Wall Thicknesses Used by INPLANTTable D-1: Commercial Steel Pipe Based on ANSI B36.10:1970 and BS 1600: Part 2: 1970 Schedule Wall Thicknesses

Nominal Pipe Size (in)

Outside Diameter (mm)

Thickness (mm)

Inside Diameter (mm)

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14 355.6 6.35 342.9

16 406.4 6.35 393.7

18 457.2 6.35 444.5

20 508.0 6.35 495.3

24 609.6 6.35 596.9

30 762.0 7.92 746.2

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8 219.1 6.35 206.4

10 273.0 6.35 260.3

12 323.9 6.35 311.2

14 355.6 7.92 339.8

16 406.4 7.92 390.6

18 457.2 7.92 441.4

20 508.0 9.52 489.0

24 609.6 9.52 590.6

30 762.0 12.70 736.6

PIPEPHASE Keyword Manual D-1

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08 219.1 7.04 205.0

10 273.0 7.80 257.4

12 323.9 8.38 307.1

14 355.6 9.52 336.6

16 406.4 9.52 387.4

18 457.2 11.13 434.9

20 508.0 12.70 482.6

24 609.6 14.27 581.1

30 762.0 15.88 730.2

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1/8 10.3 1.73 6.8

1/4 13.7 2.24 9.2

3/8 17.1 2.31 12.5

1/2 21.3 2.77 15.8

3/4 26.7 2.87 21.0

1 33.4 3.38 26.6

1-1/4 42.2 3.56 35.1

1-1/2 48.3 2.68 40.9

2 60.3 3.91 52.5

2-1/2 73.0 5.16 62.7

3 88.9 5.49 77.9

3-1/2 101.6 5.74 90.1

4 114.3 6.02 102.3

5 141.3 6.55 128.2

6 168.3 7.11 154.1

8 219.1 8.18 202.7

10 273.0 9.27 254.5

12 323.9 10.31 303.3

14 355.6 11.13 333.3

16 406.4 12.70 381.0

18 457.2 14.27 428.7

20 508.0 15.09 477.8

24 609.6 17.48 574.6



Thickness (mm)


D-2 Default Values of Schedule Pipe Sizes

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08 219.1 10.31 198.5

10 273.0 12.70 247.6

12 323.9 14.27 295.4

14 355.6 15.09 325.4

16 406.4 6.64 373.1

18 457.2 19.05 419.1

20 508.0 20.62 466.8

24 609.6 25.61 560.4

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1/8 10.3 2.41 5.5

1/4 13.7 3.02 7.7

3/8 17.1 3.20 10.7

1/2 21.3 3.73 13.8

3/4 26.7 3.91 18.9

1 33.4 4.55 24.3

1-1/4 42.2 4.85 32.5

1-1/2 48.3 5.08 38.1

2 60.3 5.54 49.2

2-1/2 73.0 7.01 59.0

3 88.9 7.62 73.7

4 114.3 8.56 97.2

5 141.3 9.52 122.3

6 168.3 10.97 146.4

8 219.1 12.70 193.7

10 273.0 15.09 242.8

12 323.9 17.47 289.0

14 355.6 19.05 317.5

16 406.4 21.44 363.5

18 457.2 23.82 409.6

20 508.0 26.19 455.6

24 609.6 30.96 547.7

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8 219.1 15.09 188.9

10 273.0 18.26 236.5

12 323.9 21.44 281.0

14 355.6 23.82 308.0

16 406.4 26.19 354.0

18 457.2 29.36 398.5

20 508.0 32.54 422.9

24 609.6 38.89 531.8



Thickness (mm)


PIPEPHASE Keyword Manual D-3

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204 114.3 11.13 92.0

5 141.3 12.70 115.9

6 168.3 14.27 139.8

8 219.1 18.26 182.6

10 273.0 21.44 230.1

12 323.9 25.40 273.1

14 355.6 27.79 300.0

16 406.4 30.96 344.5

18 457.2 34.92 387.4

20 508.0 38.10 431.8

24 609.6 46.02 517.6

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8 219.1 20.62 177.9

10 273.0 25.40 222.2

12 323.9 28.58 266.7

14 355.6 31.75 292.1

16 406.4 36.52 333.4

18 457.2 39.69 377.8

20 508.0 44.45 419.1

24 609.6 52.39 504.8

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1/2 21.3 4.78 11.7

3/4 26.7 5.56 15.6

1 33.4 6.35 20.7

1-1/4 42.2 6.35 29.5

1-1/2 48.3 7.14 34.0

2 60.3 8.74 42.8

2-1/2 73.0 9.52 54.0

3 88.9 11.13 66.6

4 114.3 13.49 87.3

5 141.3 15.88 109.5

6 168.3 18.26 131.8

8 219.1 23.01 173.1

10 273.0 28.58 215.8

12 323.9 33.34 257.2

14 355.6 35.71 284.2

16 406.4 40.49 325.4

18 457.2 45.24 366.7

20 508.0 50.01 408.0

24 609.6 59.54 490.5



Thickness (mm)


D-4 Default Values of Schedule Pipe Sizes

PIPEPHASE Keyword Manual E-1

Appendix E User-Definable Nominal Pipe Sizes

Format for User-Created NPS Database

The following is the format of the user-created database of nominal pipe sizes. The files must have the *.DAT extension, e.g., Names.DAT.

FIELD DATA DESC FORMAT

Description Character CC......C (Maximum length 20)

Pipe Schedule Character CCCC

Nominal Diameter (inches) Real RRR.RR

Inside Diameter (inches) Real RRR.RR

Inside Diameter (millimeter) Real RRRR.RR


Index

A

Abandonment pressure 4-111

ACCELERATION 4-44

Accelerationnetwork solution 4-44pressure gradient 3-29

ACENTRIC 4-37

Acentric factor 4-37

Adiabaticcompressor 4-104efficiency 4-102, 4-104

ADJUST 4-58

Adjustformation volume factor 4-59gas oil ratio 4-59water-oil viscosity 4-62

Airdensity of surrounding 4-93thermal conductivity 4-24, 4-93velocity 4-93viscosity of surrounding 4-93

Ambient temperature 3-38, 4-24, 4-93

Angleof bend 4-124of contraction device 4-129of expansion device 4-132of valve 4-135

Angle valve 4-134

ANNULUS 4-94

Annulus 3-25, 4-94depth 4-94flow efficiency 4-95heat transfer calculations 3-38heat transfer coefficient 4-25, 4-95inside diameter 4-25medium 4-97Palmer correction factors 4-94pressure drop correlations 3-27roughness 4-95segment size 4-94, 4-95segmentation 4-26specific heat of medium 4-97

thermal conductivity of medium 4-97velocity of medium 4-97viscosity of medium 4-97

API gravity 4-37, 4-82

API statement 4-37

ASSAY 4-35

Assayin source 4-76

Assay data 3-11, 4-32API gravity 4-37characterization 4-35cutpoints 4-32, 4-37lightends 4-83method 4-35molecular weight 4-35, 4-83specific gravity 4-35

ASTMD1160 4-81D2887 4-81D86 4-81

Automatic segmentation 4-27

Auxiliarypower for pump 4-121

B

Ball valve 4-134

Basismass 4-20measurement 4-10

BEND 4-124

Bend 4-124angle 4-124elbow 4-124mitre 4-124pressure drop calculation 3-33resistance coefficient 4-124roughness 4-125user-defined pressure drop 4-125

Benedict-Webb-Rubin-Starling 4-53

Binaryinteraction parameters 3-13

user-supplied 4-47

PIPEPHASE Keyword Manual I-1

Blackoiladjust properties 4-58compositional properties 4-57compressibility 4-58contaminants 4-58fluid properties 4-57formation volume factor 4-62fraction in link 4-91gas oil ratio 4-61generated properties 4-66gravity 4-57, 4-62IPR 4-80pressure 4-59tabular properties 4-59viscosity 4-57, 4-58, 4-61

Blackoil properties 3-19contaminants 3-19formation volume factor 3-19, 3-20gas oil ratio 3-19, 3-20gas Z-factor 3-19gravity 3-19lift gas 3-19live viscosity 3-19viscosity method 3-19

Bottomholecompletion 3-25completion calculation 3-31minimum pressure 4-111separator 3-37

Buried pipe 3-38, 4-24, 4-93depth 4-25partially buried 4-93

Butterfly valve 4-134

BWRS 4-53

C

CALCULATION 4-20

Calculationaccelerated 4-44automatic segmentation 4-27keywords 4-20limits 3-8maximum segments 4-26modes 2-3network method 4-88phase-splitting at junction 4-89Prandtl number 4-20segment 4-26solubility 4-52

tolerances 4-44

Calculation segment 2-8joining together 2-8

Calculation typeselecting 4-20

Calculations 3-4heat transfer 3-37isothermal 4-20pressure drop 3-27sphering 4-20

Calculator 3-26

Case study 3-5, 3-45data category 4-7global changes 3-46individual changes 3-46output 5-34report 5-13

Casingdiameter 4-96emissivity 4-97thermal conductivity 4-96

Casings 4-96

Categories of input 4-7case study data 4-7component data 4-7general data 4-7, 4-13line sizing data 4-7network data 4-7PVTdata 4-7sensitivity analysis data 4-7structure data 4-7thermodynamic data 4-7time-stepping data 4-7unit operations 4-7unit operations data 4-137

Chebychev equations 4-39

CHECK 4-125

Check data 4-20

Check valve 4-125, 4-134pressure drop calculation 3-33

Chisholm flow model 4-125–4-136

Chisholm two-phase correction 3-34

CHOKE 4-125

Choke 4-125in a well 4-126multi-networks 4-127pressure drop calculation 3-33

Coefficientflow 4-132, 4-133, 4-136

I-2 PIPEPHASE Keyword Manual

Fortunati 4-128Hazen-Williams 4-95, 4-96Hazen-Williams pressure drop 4-26, 4-93resistance for bend 4-124resistance for contraction 4-129resistance for entrance 4-130resistance for exit 4-131resistance for expansion 4-132resistance for tee 4-134resistance for valve 4-135thermal expansion 4-97

Comments 4-9

COMPLETION 4-101

Completion 3-25, 4-98, 4-101dual 4-90gravel permeability 4-101methods 4-101multiple 3-43performation 4-101pressure drop calculation 3-31tunnel 4-101

COMPONENT 4-33

Componentdata category 4-7identifier 4-34input data in report 5-8list 4-33mixed types 3-11properties from SIMSCI databank 4-34

Componentscapabilities 3-11fixed properties 4-37library 3-9, 4-34non-library 3-10, 4-33other property requirements 3-12petroleum pseudocomponents 3-10, 4-34solid 4-33structure 3-12synthetic 3-12synthetic fuel 4-33temperature dependent properties 4-37user-defined 3-10

Composition 4-77

Compositionalblackoil viscosity 4-57component list 4-33fluid properties 3-8, 4-56fluid viscosity 4-56source 4-78sources 3-21

Compressibilityblackoil 4-58

Compressibility factor 4-37, 4-62

COMPRESSOR 4-102

Compressorcoolers 4-104multispeed 3-34multistage 3-34multi-train 4-103rigorous 3-34simple 3-34, 4-102

Condensate 3-18contaminants 4-57gravity 4-56properties 4-56

Condensate gas ratio 4-77

CONDUCTIVITY 4-38

Conductivity 4-38

Contaminantsblackoil 3-19, 4-58condensate 4-57gas 3-17, 3-18, 4-55lift gas 4-59

Continuing statements 4-11

CONTRACTION 4-128

Contractionpressure drop calculation 3-33

Contraction device 4-128angle 4-129resistance coefficient 4-129user-defined pressure drop 4-129

Convergence 3-22, 4-26, 4-91flow tolerance 4-91iterations 4-27parameters 4-40power 4-107pressure balance solution method 2-9

COOLER 4-105

Cooler 3-35, 4-105interstage duties 4-104interstage temperatures 4-104

CORRELATION 4-62

Correlationformation volume factor 4-62gas oil ratio 4-62options 4-62viscosity 4-62

CP 4-38

Critical


pressure 4-37temperature 4-37volume 4-38

Critical flowin choke valves 4-42

Crushed zone 4-101

CSOURCE 4-78

Curvesperformance 4-104

CUTPOINTS 4-37

Cutpoints 4-32, 4-37

D

D1160 4-81

D2887 4-81

D86 4-81

Dead-end tee 4-89

DEFAULT 4-24

Defaultflow device parameters 3-7heat transfer 3-7limits 3-8pressure drop methods 3-7thermodynamic set 3-15transitional flow 3-8

Default data 4-9, 4-24

Defaults 3-7

Definitionflow device parameters 3-7fluid properties 3-8heat transfer 3-7limits 3-8non-compositional properties 3-16pressure drop methods 3-7pseudo-component 3-10pseudocomponent data 3-10pseudocomponent methods 3-10pseudocomponent variable data 3-11transitional flow 3-8

DENSITY 4-38

Density 4-38liquid 4-33methods 3-13of surrounding medium 4-24, 4-93Rackett parameter 4-33results 5-31shot 4-101

standard 4-37thermodynamic method 4-48

Denstiyof annular medium 4-97

Depletionreservoir 3-42

Depthof annulus 4-94of buried pipe 4-93oftubing 4-96

DESCRIPTION 4-14

Descriptive text 3-5general data 4-14

Design mode 3-5

Devicelink output 5-23report 5-21

Devices 3-6

Diameteractual inside 4-25nominal 3-30nominal inside 4-25of hole 4-96of sphere for pigging 4-93outside for annulus tubing 4-94

Diamterinside annulus 4-94of casing 4-96of tubing 4-96

Diffusivityof the earth 4-97

Dipole moment 4-33

Discharge pressure 4-103

Distillation data 4-81TBP 4-81

Distillation data statement 4-80

DPDT device 3-35, 4-105in well 4-106

dual 4-98

Dual completions 4-90, 4-98parallel 4-99

E

Efficiency 4-102adiabatic 4-104of flow 4-25


of pump 4-121performance curves 4-104polytropic 4-104

Elbow bend 4-124

Electric submersible pump 3-36, 4-121

Elevation pressure gradient 3-29

Emissivityof casing 4-97of tubing 4-97

Emulsionviscosity 4-62

Englishunits of measurement 4-15, 4-16

ENTHALPY 4-38

Enthalpy 3-12, 4-38aqueous phase 3-13convergnece tolerance 4-26methods 3-13thermodynamic method 4-48

ENTRANCE 4-129

Entrance device 4-129pressure drop calculation 3-33resistance coefficient 4-130

Equation of stateinteraction parameters 4-53

Equipmentdevice summary report 5-21devices 4-101keywords 4-101

Equipment devices 3-24completion 3-25fittings 3-25process 3-25unit operations 3-26

Equipment items 3-34

EVALUATE 4-145

EXIT 4-130

Exit device 4-130pressure drop calculation 3-33resistance coefficient 4-131user-defined pressure drop 4-131

EXPANDER 4-106

Expander 3-35, 4-106

EXPANSION 4-131

Expansionpressure drop calculation 3-33

Expansion device 4-131angle 4-132

resistance coefficient 4-132user-defined pressure drop 4-132

F

Facilities planning 3-42

Factorcompressibility 4-62Palmer correction 4-92, 4-94, 4-96UOP characterization 4-82volume formation 4-59, 4-62WatsonK characterization 4-82z 4-62

FCODE 4-21

Field datamatching 4-25

Field Production, application 2-4

FILE 4-70

Film coefficient 4-25, 4-93

Fittingdevice summary report 5-21schedule 4-25

Fittingsavailable fittings 3-25pressure drop calculation 3-32two-phase correction 3-34

Fixed property requirements 3-12

Flashreport 5-4, 5-19results 3-6

Flowbasis in IPR 4-111coefficient for nozzle 4-132coefficient for orifice 4-133coefficient for venturimeter 4-136device summary report 5-21efficiency 4-25efficiency in annulus 4-95efficiency in pipe 4-93efficiency in tubing 4-96maximum rate 4-90minimum rate 4-91rate 4-76tolerance 4-44, 4-91

Flow devices 2-3, 3-24annulus 3-25calculations 3-28inflow performance 3-25


keywords 4-92parameters 3-7pipe 3-24sizing 3-26tubing 3-25

Flow regimeTaitel-Dukler map 5-30

Flowrateperformance curves 4-104

Flowratesselecting 3-47

Fluidproperty interpolation 4-44

Fluid propertiesadjust blackoil 4-58blackoil 3-19, 4-57compositional 3-8compositional blackoil 4-57compositional fluid 4-56condensate 4-56correlation options 4-62defining 3-8gas condensate 3-18, 4-56lift gas 4-59non-compositional 3-16non-compositional gas 3-17, 4-55non-compositional liquid 3-17, 4-55steam 3-18, 4-55water solubility in hydrocarbons 3-9

Fluid type 2-3selecting 4-20

Foot valve 4-134

Formation volume factor 3-19adjusting 4-59correlations 4-62tablular data 4-62

Fortunati Model 4-128, B-2

Friction results 5-31

Frictional pressure gradient 3-28

Fugacityvapor 4-47

FVF 4-62

G

Gascondensate contaminants 4-57condensate gravity 4-56

condensate properties 4-56contaminants 4-55gravity 4-55non-compositional properties 4-55volume fraction in link 4-91z-factor 4-62

Gas liftfluid properties 4-59

Gas lift analysis 3-4gas lift valve 3-35

Gas lift valve 3-35, 4-107

Gas oil ratio 3-19, 4-77, 4-88, 4-89, 4-91, 4-139, 4-144

adjusting 4-59correlations 4-62maximum 4-111shutdown 4-111tabular data 4-61

Gas propertiescondensate 3-18contaminants 3-17, 3-18non-compositional 3-17specific heat ratio 3-17Z-factor 3-17

Gasliftdata category 4-7input data report 5-15

Gaslift analysis 2-4, 3-39

gaslift data 4-7

Gathering systems 2-4

GENERAL 4-13

GENERATE 4-66

Generated properties 3-20blackoil 4-66output 5-16print options 4-65, 4-67read from file 4-70

Geothermalgradient 4-97

Geothermal gradient 3-25, 3-38, 4-24, 4-95, 4-96

Gereral data 4-13

GF choke models 6-64

Global changescase study 3-46

Global defaultsetting 4-24

Global parameters 4-13

Global settings 3-5


Globe valve 4-134

GLVALVE 4-107

Gradientgeothermal temperature 4-24

GRAVITY 4-62

GravityAPI 4-82blackoil 4-57, 4-62condensate 4-56gas 4-16, 4-55lift gas 4-59liquid 4-55specific 4-82standard liquid 4-82steam 4-56tabular data 4-62

Gravity data 4-82

Grouping parameters 3-48

Gyrationradius 4-33

H

Hayden-O’Connell method 4-33

Hazen-Williamscoefficient 4-93, 4-95, 4-96method 4-26

Headperformance curves 4-104

Heatlatent 4-38specific 4-38

Heat capacityratio 4-55

Heat transfer 3-7additional resistance 4-25, 4-93calculations 3-37detailed for tubing 4-96results 5-32

Heat transfer coefficientannulus 4-25, 4-95film coefficient 4-25, 4-93for buried pipe 4-24overall 2-8overall value 4-24pipe 4-93radiant 4-25, 4-93riser 4-25

tubing 4-25, 4-96

HEATER 4-107

Heater 3-35, 4-107

Henrys Law 4-47

Hildebrand solubility 4-33

Holdupoutput 5-28Palmer correction factors 4-21

Holediameter 4-96

Homogeneous two-phase correction 3-34

Homogeneous two-phase flow model 4-125–4-136

Hydrateprediction output 5-32

Hydrate prediction 4-144

HYDRATES 4-144

I

Inflow performacepseudo-pressure 4-114

Inflow performance 3-21, 3-49method 4-80relationship 3-25, 3-42, 4-77, 4-109relationships 3-40results 5-18tabular data 4-117time-stepping 4-118well data 4-118

INJECTION 4-108

Injection 4-90, 4-108device in well 4-108scrubber fluids 4-104time 4-97well 4-88

Injection device 3-35

injection device 4-108

Inputcategories 4-7comments 4-9component report 5-8continuing statements 4-11data check 4-20defaults 4-9gaslift data 5-15general data category 4-13general data report 5-9in results output 5-3


keyword qualifiers 4-8keywords 4-8layout 4-11lift gas data 5-15network data report 5-11nodal analysis report 5-15PVT data report 5-10source data report 5-11structure data report 5-12thermodynamic report 5-8title 4-14unit operations data category 4-137units of measurement 4-10

Input data check 3-5

Input reprint 3-6

Inside diameteractual 4-25annulus 4-25fittings 4-25nominal 4-25pipe 4-25tubing 4-25

Insulationthermal conductivity 4-25thickness 4-25, 4-93

Insulation requirement 2-5

Interaction parameters 4-53

Interpolatereservoir decline curves 4-110

Interstagecooler duties 4-104temperatures 4-104

Inversion 4-62

IPR 4-109Inflow Performance Relationship 4-211cumulative production 4-117flow basis 4-111

IPR curves 3-41

Isothermalcalculations 3-38calculations, specify globally 4-20

Iterations 4-27

Iterative results 3-6

J

Joule-Thomson effect 2-3

JUNCTION 4-88

Junctiondead-end tee 4-89rock formation 4-89straight-through tee 4-89subsurface 4-89

Junction-phase-splitting method 4-89

K

Keyword input 4-9calculation 4-20continuing statements 4-11conventions 4-11keywords 4-8layout 4-11qualifiers 4-8units of measurement 4-10

Keywordsequipment devices 4-101flow device 4-92GENERAL 4-13system nodes 4-75unit operations data 4-137

K-value 3-12thermodynamic method 4-48

L

Laminar flowllimit 4-21

LATENT 4-38

Latent heat 4-38

Lee-Kessler-Plocker 4-53

Legend for description 4-11

Lengthof annulus segment 4-26of pipe segment 4-26of riser segment 4-26of tubing segment 4-26

LIBID 4-34

Library components 3-9, 4-34

Lift gascontaminants 4-59gravity 4-59input data report 5-15properties 3-19, 4-59

LIFTGAS 4-59


LIGHTENDS 4-83

Lightends 3-11in assay 4-83

Line sizing 3-26data category 4-7default diameters 5-14report 5-14schedule 4-25

LINK 4-89

Link 2-7, 4-89device summary report 5-21individual print option 4-91injection 4-90joining together 2-9output 5-23, 5-30property detail output 5-30report 5-20summary 5-5

Liquidactivity methods 4-47gravity 4-55molar volume 4-33non-compositional properties 4-55single-phase IPR 4-80standard gravity 4-82

Liquid density 3-12Rackett parameter 4-33

Liquid holdupPalmer correction 4-92, 4-94, 4-96Palmer correction factors 4-21

LKP 4-53

M

Mass basis 4-20

Matching field data 4-25

Materialthermal conductivity 4-25

Maximum power 4-102

Maximum pressure 4-102

Maximum speed 4-102

MCHOKE 4-127

MCOMPRESS 4-103

Measurementbasis 4-10

Mediumannular 4-97conductivity of surrounding 4-24

density of surrounding 4-24, 4-93specific heat of annular 4-97surrounding pipe 4-24, 4-92temperature of surrounding 4-93thermal conductivity 4-93thermal conductivity of annular 4-97type of annular 4-97velocity of annular 4-97velocity of surrounding medium 4-93viscosity of annular 4-97viscosity of surrounding 4-24, 4-93

METHOD 4-48

MethodChisholm 4-125–4-136for completion device 4-101Henry’s Law 4-47Homogeneous two-phase 4-125–4-136inflow performance 4-80liquid activity 4-47network 4-88phase-splitting at junction 4-89prediction 3-14thermodynamic 4-48UNIFAC 4-33, 4-47UNIQUAC 4-33UNIWAAL 4-47viscosity 3-17

Metricunits of measurement 4-15, 4-16

Mitre bend 4-124

Mixed component types 3-11

Mixed fluid properties 3-20

Molecular weight 4-37assay 4-83of pseudocomponent 4-35

MREGULATOR 4-128

MW 4-37

N

NETWORK 4-40

Network 2-7accelerated calculations 4-44acceleration 4-44calculation method 4-88connectivity plot 5-13convergence 3-22, 4-91convergence parameters 4-40data category 4-7


initial estimates 3-22input data in report 5-11junctions 3-23links 3-23pressure balance solution method 2-9results 5-17solution 4-40steam 3-24structure 3-22subnetwork 3-24subsurface 3-41, 3-43tolerance 4-44

Network Well-Posedness 6-96

Nodal analysis 3-5, 3-47data category 4-7dividing links 3-47input data report 5-15output 5-35results 3-47selecting flowrates 3-47selecting parameters 3-47variables 3-48

Nodereports 4-30, 5-5, 5-21sensitivity analysis 3-48solution 3-48system 4-75

Nominalinside diameter 3-30, 4-25

Non-compositionalfluid properties 3-16, 4-55gas properties 3-17, 4-55sources 3-21

Non-library components 4-33

Normal boiling point (NBP) 4-37

NOZZLE 4-132

Nozzle 4-132flow coefficient 4-132pressure drop calculation 3-33user-defined pressure drop 4-133

O

of annular medium 4-97

ORIFICE 4-133

Orifice 4-133flow coefficient 4-133pressure drop calculation 3-33user-defined pressure drop 4-133

OUT-DIMENSION 4-31

Outputcase study 5-13, 5-34component input 5-8density 5-31friction 5-31general input data 5-9heat transfer 5-32holdup 5-28hydrate prediction 5-32lift gas input 5-15link property detail 5-30network connectivity 5-13network input data 5-11nodal analysis 5-15, 5-35pipe diameter 5-14pressure gradient 5-29print options 4-28PVT input data 5-10results 5-4, 5-17Results Access System 4-29, 5-38slug 5-33solutions 5-19source input data 5-11sphering 5-37structure input data 5-12surface tension 5-31thermodynamic input 5-8units of measurement 4-31velocity 5-28viscosity 5-31

Output units 3-6

Outside diamtertubing 4-25

P

Palmer liquid holdupcorrection factors 4-21

Palmer liquid holdup correction factorsin annulus 4-94in pipes 4-92in tubing 4-96

Parallel compressor trains 4-104

Parameterdefinition 3-48Hildebrand solubility 4-33

Parametersbinary interaction 4-47


convergence 4-40interaction 4-53selecting 3-47

parametersgrouping 3-48

PC 4-37

Perforationsin completion device 4-101

Performanceinflow 4-109

Performance curves 4-104

Performance relationship 3-25, 4-77

Permeabilitycrushed zone 4-101of gravel in completion 4-101

PETROLEUM 4-34

Petroleumpseudocomponents 4-34units of measurement 4-15, 4-16

Phase envelopeoutput 5-26plot 5-27

Phase separation 3-12

Pigging 3-40sphere diameter 4-93time step 4-26

PIPE 4-92

Pipe 3-24, 4-92buried 3-38, 4-24buried partially 4-93density of surrounding 4-93depth of buried 4-25, 4-93diameter in report 5-14flow efficiency 4-93heat transfer 3-38heat transfer calculations 3-38heat transfer coefficient 4-93insulation thickness 4-93Palmer correction factors 4-92pressure drop correlations 3-27roughness 4-25, 4-92schedule 4-25segment size 4-94segmentation 4-26sizing data output 5-14surrounded by air 3-38surrounded by soil 3-38surrounded by water 3-38surrounding medium 4-24, 4-92temperature of surrounding 4-93

thermal conductivity 4-25, 4-93thermal conductivity of surrounding 4-93thickness 4-25, 4-93velocity of surrounding 4-93viscosity of surrounding 4-93

Pipe schedule 3-30from external file 4-25

Piping structure 3-4

Planningfacilities 3-42production 3-41

Plotphase envelope 5-27pressure 5-25temperature 5-25

Plotting options 3-7

Plotting results 3-7

Polytropiccompressor 4-104efficiency 4-104

Powerauxiliary for pump 4-121available 4-103maximum 4-102of pump 4-120

PR 4-53

Prandtl numberrigorous calculation 4-20

Prediction methods 3-14

Pressureabandonment 4-111change device 4-105convergence tolerance 4-26critical 4-37difference 3-35discharge 4-103drawdown 3-40gradient report 5-29interstage compressor 4-104losses 4-104maximum 4-102, 4-111minimum bottom hole 4-111plot 5-25pseudo 4-114report 5-24reservoir 4-59shutdown 4-111suction 4-104tolerance 4-44user-define drop through bend 4-125


user-define drop through contraction 4-129user-define drop through exit 4-131user-define drop through expansion 4-132user-define drop through nozzle 4-133user-define drop through orifice 4-133user-define drop through tee 4-134user-define drop through valve 4-135user-define drop through venturimeter 4-136vapor 4-38

Pressure balance solution method 2-9

Pressure dropacross segment 4-26calculations 3-27, 3-28completion calculation 3-31correlations 3-27, 4-21fitting calculation 3-32Hazen-Williams method 4-26selecting global correlations 4-21

Pressure Drop Methods 2-4

Pressure drop methods 3-7

Pressure gradientacceleration 3-29elevation 3-29frictional 3-28

Pressure limits 3-8

Pressure ratiowarning 4-105

PRINT 4-28

Print options 3-6, 4-28devices 3-6flash results 3-6for individual links 4-91generated properties 4-65, 4-67input reprint 3-6iterative results 3-6output units 3-6plotting options 3-7properties output 3-6Results Access System 3-7

Priorityof sources 4-76shut in 4-76

Process equipment 3-34available equipment items 3-25

Productiondecline rates 3-42

Production planning 3-41

production planning 3-41

Propertiesgenerated 3-20interpolations 4-44tabular 3-20

Properties output 3-6

Propertyadjust 4-58blackoil 4-57compositional fluid 4-56condensate 4-56correlation options 4-62lift gas 4-59non-compositional 4-55non-compositional gas 4-55read from file 4-70set for streams 4-54steam 4-52, 4-55tablular blackoil 4-59water 4-52

Pseudocomponents 3-10, 4-34fixed property data 3-10properties 4-35property calculation methods 3-10specific gravity 4-35variable property data 3-11

Pseudo-pressureformulation 4-114

Pseudo-pressure formulation 3-41

PUMP 4-119

Pump 4-119auxiliary power 4-121curve 4-120degradation 4-121efficiency 4-121electric submersible 3-36, 4-121in a well 4-121multispeed 3-36power 4-120power and duty 2-5RILING correction 4-120simple 3-36

PVTsimulation 4-20tables 4-20

PVT datainput data in report 5-10

PVTGEN results 5-16


Q

Qualifiers 4-8

Qualitysteam 3-50, 4-77

Quality of steam 3-21

R

Rackett parameter 4-33

Radiant heat transfer resistance 4-25, 4-93

Radiusof curvature 4-124of gyration 4-33

Rating mode 3-5

REGULATOR 4-121

Regulator 4-121multi-network 3-36, 4-128simple 3-36

Reportcase study 5-13component input 5-8device summary results 5-21flash results 5-19gaslift input data 5-15general input data 5-9holdup 5-28inflow performance 5-18lift gas input 5-15link detail 5-23link property detail 5-30link summary results 5-20network connectivity 5-13network input data 5-11nodal analysis input 5-15node 4-30node summary results 5-21pipe diameters 5-14pressure 5-24pressure gradient 5-29PVT input data 5-10PVTGEN results 5-16results 5-17results summary 5-23separator results 5-20slug 4-29, 5-33solution 5-19source input data 5-11

sphering 5-37structure data summary 5-22structure input data 5-12temperature 5-24thermodynamic input 5-8velocity 5-28velocity summary 5-22

Reservoir 3-41decline data 4-109depletion 3-42interpolate decline curves 4-110multiple 3-40pressure 4-59pressure drawdown 3-40relationships 3-40temperature 4-58time-stepping 3-41well data 4-118

Reservoir curves 3-40

Reservoir data 4-117

Resistance coefficientbend 4-124contraction 4-129entrance 4-130exit 4-131expansion device 4-132tee 4-134valve 4-135

ResultsAccess System 4-29, 5-38case study 5-34density 5-31device summary 5-21flash 5-19friction 5-31heat transfer calculation 5-32hydrate prediction 5-32inflow performance 5-18input reprint 5-3intermediate printout 5-4, 5-17link detail 5-23link summary 5-20network directory 5-17nodal analysis 3-47, 5-35node summary 5-21output 5-4output dimensions 4-31pressure 5-24reports 5-3sensitivity analysis 3-47separator 5-20


solution output 5-19sphering 5-37structure data summary 5-22summary 5-23surface tension 5-31temperature 5-24tolerances 4-44velocity summary 5-22viscosity 5-31

Results Access System 3-7output 4-29, 5-38

Reynolds numberlimit for laminar flow 4-21

RILING correction 4-120

Riserheat transfer calculations 3-38heat transfer coefficient 4-25pressure drop correlations 3-27segment size 4-94segmentation 4-26

Roughnessof annulus 4-95of bend 4-125of pipe 4-25, 4-92of tee 4-134of tubing 4-96

S

Saturated steam 3-18

Scheduledefault fitting 4-25default pipe 4-25default tubing 4-25from external file 4-25line sizing 4-25pipe 3-30

Scrubber fluids 4-104

SEGMENT 4-26

Segmentautomatic 4-27length for annulus 4-26length for pipe 4-26length for riser 4-26length for tubing 4-26maximum number 4-26number of 4-94, 4-95, 4-97pressure drop 4-26size 4-94, 4-95, 4-97

temperature drop 4-26

Segmentationof links 4-26

Sensitivity analysis 3-5, 3-47data category 4-7dividing links 3-47output 5-35results 3-47selecting flowrates 3-47selecting parameters 3-47variables 3-48

SEPARATOR 4-122

Separator 3-37, 4-122bottomhole 3-37in a well 4-123injection 3-35report 5-20

SET 4-54

Set global defaults 4-24

SGOR 4-61

Shotdensity in completion device 4-101

Shut inpriority 4-76

Shutdowngas oil ratio 4-111pressure 4-111

SIunits of measurement 4-15, 4-16

SIMSCI databankcomponent properties 4-34

Simulationusing PVT tables 4-20

Sizingflow devices and lines 3-26

Slugreport 4-29, 5-33

Soilthermal conductivity 4-25, 4-93

Solidcomponents 4-33

Solubilityparameter 4-33water in hydrocarbons 3-9

SOLUTION 4-40

Solutiongas oil ratio 4-59, 4-61gas oil ratio correlations 4-62


Solution node 3-48

SOURCE 4-75

Sourceassays in 4-76composition 4-77compositional 3-21, 4-78input data in report 5-11non-compositional 3-21

Sourcesshutting down 4-109

Specific gravity 3-19, 4-37, 4-82for assays 4-35

Specific heat 4-38of annular medium 4-97ratio 4-55

Speedmaximum 4-102

SPGR 4-37

Sphering 3-4, 3-40, 4-26invoking calculations 4-20output 5-37slug catcher sizing 2-6

Spur link 6-77

SRK 4-53

Stagesnumber for pump 4-121number of compressor 4-102, 4-104

STDDENSITY 4-37

Steamexpander 3-35, 4-106gravity 4-56network 3-24properties 3-18, 4-52, 4-55quality 3-18, 3-21, 3-50, 4-77saturation 3-18

Streamname 4-75, 4-78

Structuredata category 4-7data report 5-22input data in report 5-12

Submersiblepump 3-36

Submersible pump 4-121

Subnetwork 3-24compressor 3-34regulator 3-36

Subsurfacejunctions 4-89

Subsurface networks 3-41, 3-43

Suction pressure 4-104

SURFACE 4-38

Surface tension 4-38results 5-31

Swing valve 4-134

Synthetic components 3-12

Synthetic fuel 4-33

Systemnodes 4-75thermodynamic methods 4-50

T

TABULAR 4-59

Tabular data 3-19formation volume factor 4-62gas oil ratio 4-61gravity 4-62inflow performance 4-117viscosity 4-61

Tabular properties 3-20blackoil 4-59

Taitel-Duklerflow regime map 5-30

TBP distillation property 4-81

TC 4-37

TEE 4-133

Tee 4-133dead-end 4-89pressure drop calculation 3-33resistance coefficient 4-134roughness 4-134straight-through 4-89user-defined pressure drop 4-134

Temperatureambient 3-38, 4-24, 4-93change device 4-105critical 4-37difference 3-35drop across segment 4-26geothermal gradient 4-24, 4-95, 4-96interstage 4-104of rock formation 4-89plot 5-25report 5-24reservoir 4-58tolerance 4-44


warning 4-105

Temperature limits 3-8

Termal expansioncoefficient 4-97

Text comments 4-9

Thermal conductivity 4-38of annular medium 4-97of casing 4-96of insulation 4-25of pipe 4-25of soil 4-25of surrounding 4-93of surrounding medium 4-24of the earth 4-97of tubing 4-96pipe material 4-93

Thermodynamicbinary interaction data 4-47capabilities 3-15data category 4-7input data in report 5-8

Thermodynamic methods 3-12, 4-48Benedict-Webb-Rubin-Starling 4-53density 3-13, 4-48enthalpy 3-13, 4-48for entire system 4-48K-value 4-48Lee-Kessler-Plocker 4-53liquid activity 4-47Peng-Robinson 4-53predefined sets 4-50Soave-Redlich-Kwong 4-53steam 4-52system 4-50UNIFAC 4-33UNIQUAC 4-33water 4-52

Thermodynamic properties 3-12aqueous phase enthalpy 3-13binary interaction 3-13multiple methods 3-15

Thicknessof insulation 4-25, 4-93of pipe 4-25, 4-93

Timeinjection 4-97production 4-97

Time stepsphering and pigging 4-26

time step 4-26

Time-stepping 3-41data category 4-7reservoir decline data 4-109well data 4-118

TITLE 4-14

TOLERANCE 4-44

Tolerance 4-44, 4-91enthalpy 4-26power 4-107pressure 4-26

Total power 4-103

Transitional flow 3-8

Transmission pipelines, application 2-5

Transport properties 3-13

TUBING 4-95

Tubing 3-25, 4-95annular medium 4-97default schedule 4-25depth 4-96detailed heat transfer 4-96diameter 4-96dual completions 4-98emissivity 4-97flow efficiency 4-96for annulus 4-94heat transfer 3-38heat transfer coefficient 4-25, 4-96inside diameter 4-25outside diameter 4-25Palmer correction factors 4-96pressure drop correlations 3-27roughness 4-96segment size 4-94, 4-97segmentation 4-26thermal conductivity 4-96time 4-97

Tubing data 3-38

Tunnelin completion device 4-101

U

UNIFAC method 4-33, 4-47

UNIQUAC method 4-33

UNIT 4-137, 4-138

Unit operations 4-138available items 3-26data category 4-7


keywords 4-137

Units of measurement 3-5, 4-10basis of measurement 4-10different output units 4-31English 4-15, 4-16metric 4-15, 4-16mulitiple dimensional units 4-10petroleum 4-15, 4-16SI 4-15, 4-16

UNIWAAL method 4-47

UOP factor 4-82

V

VALVE 4-134

Valve 4-134angle 4-135gas lift 3-35pressure drop calculation 3-33resistance coefficient 4-135user-defined pressure drop 4-135velocity constant 4-135

Van der Waalsarea and volume 4-33

Vapordensity 3-12fugacity 4-47pressure 4-38

Variablesfor sensitivity analysis 3-48

VC 4-38

Velocityconstant for valve 4-135data report 5-22of annular medium 4-97of surrounding medium 4-93output 5-28

VENTURIMETER 4-136flow coefficient 4-136pressure drop calculation 3-33user-defined pressure drop 4-136

VISCOSITY 4-38, 4-61

Viscosity 3-19, 4-38, 4-55, 4-97blackoil 4-57, 4-58, 4-61compositional fluid 4-56correlations 3-17, 4-62emulsion 4-62method 3-17

of surrounding medium 4-24, 4-93overriding 3-14overriding data 3-17results 5-31RILING correction 4-120specification 3-14tabular data 4-61

Volumecritical 4-38formation factor 4-59, 4-62fraction in link 4-91liquid molar 4-33percent of scrubber fluids 4-104

VP 4-38

W

Warningpressure ratio 4-105temperature 4-105

WATER 4-52

Waterdensity of surrounding 4-93fraction at inversion point 4-62maximum cut 4-111options 4-52percent in liquid phase 4-77properties 4-52solubility calculation 4-52thermal conductivity 4-24, 4-93velocity 4-93viscosity of surrounding 4-93volume fraction in link 4-91

Water gas ratio 4-77

Water solubility 3-9

WATSONK factor 4-82

Well 4-108abandonment pressure 4-111choke inside 4-126data for time-stepping 4-118devices 4-107flow basis 4-111hole diameter 4-96maximum gas oil ratio 4-111maximum water cut 4-111minimum bottom hole pressure 4-111pump inside 4-121separator inside 4-123well device 4-106


Well control 4-76

Wells 2-4, 2-5detailed heat transfer 4-96inflow performance 3-21injection 4-88, 4-90multiple 3-40single 3-43well devices 4-94, 4-95

Z

ZC 4-37

Z-factorblackoil 4-62gas 3-17, 4-62


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