vip-exec reference manual

VIP-EXEC® Reference Manual

© 2012 Halliburton

February 2012

© 2012 HalliburtonAll Rights Reserved

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v

Table of Contents

PrefaceAbout This Manual

Chapter 1Data Overview

1.1 Introduction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-251.1.1 VIP-COMP Overview . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-251.1.2 VIP-ENCORE Overview . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-261.1.3 VIP-DUAL Overview . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-261.1.4 VIP-POLYMER Overview . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-271.1.5 VIP-THERM Option . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-271.1.6 Shared Features . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-28

1.2 Typical Data Requirements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-301.2.1 Well Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-301.2.2 Production Histories . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-301.2.3 Pressure History . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-30

1.3 Data Deck Layout . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-31

1.4 Input Data Template . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-42

1.5 Data Format . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-471.5.1 General Utility Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-48

1.5.1.1 Comment Lines (C) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-481.5.1.2 Read Data from an External File (INCLUDE) . . . . . . . . . . . . 1-481.5.1.3 Stop Reading Data from the Current INCLUDE File (ENDINC) 1-491.5.1.4 Echo Print On (LIST) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-491.5.1.5 Echo Print Off (NOLIST) . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-491.5.1.6 Skip Data On (SKIP) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-501.5.1.7 Skip Data Off (NOSKIP) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-501.5.1.8 Columns To Be Read (NCOL) . . . . . . . . . . . . . . . . . . . . . . . . 1-501.5.1.9 Data Line Continuation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-50

1.5.2 Well Lists . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-511.5.3 Alternative Well Lists . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-51

1.6 Files Used by VIP-EXECUTIVE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-52

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1.7 Units Conventions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-55

Chapter 2Utility Data

2.1 Introduction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-57

2.2 Control . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-572.2.1 Start of Time-Dependent Data (RUN) . . . . . . . . . . . . . . . . . . . . . . . . . . 2-572.2.2 Calculate Memory Requirement (STORAGE) . . . . . . . . . . . . . . . . . . . . 2-582.2.3 Change Default Dimensions (DIM) . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-582.2.4 Material Balance Option (OPTMBL) (Not available in VIP-THERM) . 2-632.2.5 Volume Balance Option (VOLBAL) (Not available in VIP-THERM) . 2-64

2.3 Formulation Options (VIP-COMP or VIP-ENCORE) . . . . . . . . . . . . . . . . . . . . . 2-642.3.1 Implicit form of Finite Difference Equations (IMPLICIT) . . . . . . . . . . 2-642.3.2 Explicit form of Finite Difference Equations (IMPES) (Not available in VIP-THERM) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-65

2.4 Results File Control . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-652.4.1 Plot File Format and Data Selection (PLOT) . . . . . . . . . . . . . . . . . . . . . 2-652.4.2 Compositional Plot File Format and Data Selection (CPLOT) . . . . . . . 2-662.4.3 Map File Format (MAP) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-692.4.4 Flat File(s) for PLOT/MAP Instead of VDB File (NOVDB) . . . . . . . . . 2-702.4.5 VDB File for PLOT/MAP Data (VDB) . . . . . . . . . . . . . . . . . . . . . . . . . 2-702.4.6 Flow Vectors (FLOWVEC) (Not accepted by VIP-THERM, see FLOWS card in VIP-CORE manual) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-71

2.5 Pore Volume Deformation Option (PVDEF) . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-72

2.6 Conductive (Leaky) Fault Solution Options (Not available in VIP-THERM) . . . 2-732.6.1 Segregated Flow Assumption (SEGREG) . . . . . . . . . . . . . . . . . . . . . . . 2-732.6.2 Fully Coupled Calculation (LKCPLD) . . . . . . . . . . . . . . . . . . . . . . . . . . 2-73

2.7 General . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-742.7.1 Restarting Runs (RESTART) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-742.7.2 Descriptive Run Information (TITLE1, TITLE2, TITLE3) . . . . . . . . . . 2-752.7.3 Beginning of Data (START) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-752.7.4 Time Specification for Reading Data (TIME) . . . . . . . . . . . . . . . . . . . . 2-762.7.5 Date Specification for Reading Data (DATE) . . . . . . . . . . . . . . . . . . . . 2-772.7.6 Run Termination (STOP) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-772.7.7 End-of-File Marker (END) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-77

Chapter 3Well Data

3.1 Introduction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-79

3.2 Well Location . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-793.2.1 Well Name and Location (WELL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-803.2.2 Describe Well Perforations (FPERF) . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-83

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3.2.3 Describe Well Perforations, VIP-DUAL (FPERF) . . . . . . . . . . . . . . . . . 3-953.2.4 Set Status of Well Perforations (PRFSTAT) . . . . . . . . . . . . . . . . . . . . . 3-973.2.5 Well Perforation Tolerances (PERFPT) . . . . . . . . . . . . . . . . . . . . . . . . . 3-993.2.6 Inclined and Horizontal Well Flow Correlation (BEGGS) . . . . . . . . . 3-1003.2.7 Wellbore Friction Pressure Loss (NOFRICTION) . . . . . . . . . . . . . . . . 3-100

3.3 Surface Separation Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1013.3.1 Compositional Separator Battery, VIP-COMP or VIP-THERM (SEPARA-TOR) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1013.3.2 Black-Oil Separator Battery, VIP-ENCORE (SEPARATOR) . . . . . . . 3-1043.3.3 K-Value Separation Data, VIP-ENCORE (SEPARATOR) . . . . . . . . . 3-1073.3.4 Gas Plant Data Input (GASPLANT) (Not available in VIP-THERM) 3-1103.3.5 Separator Switching (NEWSEP) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1123.3.6 Surface Facility Model Input (TSFM) . . . . . . . . . . . . . . . . . . . . . . . . . 3-113

3.4 Well Type . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1143.4.1 Production Well Definition (PROD) . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1153.4.2 Injection Well Definition (INJ) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-117

3.4.2.1 Temperature Specification (VIP-THERM) . . . . . . . . . . . . . . 3-1193.4.2.2 Steam Quality Specification (VIP-THERM) . . . . . . . . . . . . . 3-1203.4.2.3 Pressure Specification (VIP-THERM) . . . . . . . . . . . . . . . . . 3-1203.4.2.4 Treatment of Water/Steam Injectors (VIP-THERM) . . . . . . 3-120

3.4.3 Define Additional Injection Rate for FSTD or FRES Wells (INJA) . . 3-1243.4.4 Computation of Mobility for Gas Injectors (GINJMOB) . . . . . . . . . . . 3-1243.4.5 Computation of Mobility for Water Injectors (WINJMOB) . . . . . . . . 3-1253.4.6 Production Rates Outer Iteration Number (ITNSTP) . . . . . . . . . . . . . . 3-1253.4.7 Water Injection Rates Outer Iteration Number (ITNSTQ) . . . . . . . . . . 3-1253.4.8 Gas Reinjection Rates Outer Iteration Number (ITNGRE) . . . . . . . . . 3-1273.4.9 Change Well Type Class (WLTYCH) . . . . . . . . . . . . . . . . . . . . . . . . . 3-1283.4.10 Extra Pass to Compute Produced Gas Composition (REINJCOMP) . 3-130

3.5 Well Constraints . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1313.5.1 Maximum Rate (QMAX) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1313.5.2 Water Limit - Water Cut, Rate or Liquid-Gas Ratio Constraint (WLIMIT) . 3-1323.5.3 Gas Limit - GOR or Rate Constraint (GLIMIT) . . . . . . . . . . . . . . . . . . 3-1333.5.4 . . Steam Limit - Steam Rate or Steam-Oil Ratio Constraint (SLIMIT) (VIP-THERM) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1353.5.5 Economic Limit (ECOLIM) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1363.5.6 Perforation Test Schedule (TSTPRF) . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1373.5.7 Perforation Water Cut, GOR, and/or SOR Limits (PRFLIM) . . . . . . . 3-1383.5.8 Minimum Rate (QMIN) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1393.5.9 Multiple Rate (QMULT) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1403.5.10 Injection Gas Composition (YINJ) . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1413.5.11 Define Additional Injection Gas Composition (YINJA) . . . . . . . . . . 3-1433.5.12 Injection Water Salinity (WSAL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1433.5.13 Time Interval Between Tests . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-144

3.5.13.1 Global Specification (TEST) . . . . . . . . . . . . . . . . . . . . . . . . 3-144

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3.5.13.2 Specification by Well (WTEST) . . . . . . . . . . . . . . . . . . . . . 3-1453.5.14 Fraction of Time That Well is on Stream (ONTIME) . . . . . . . . . . . . 3-1463.5.15 Well Permeability-Thickness Multiplier (WKHMULT) . . . . . . . . . . 3-1473.5.16 GOR Penalty (GORPEN) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1473.5.17 GOR Constraint (GORCON, GORLIM) . . . . . . . . . . . . . . . . . . . . . . 3-1483.5.18 Maximum Steam Rate for Producers (QSTMX) (VIP-THERM) . . . . 3-150

3.6 Pressure Constraints and Productivity Indices . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1503.6.1 Well Index (WI)(Skip if PI or FLOW orWIL or KHWI is used) . . . . 3-1543.6.2 Productivity/Injectivity Index (PI) (Skip if WI or RFLOW or WIL or KHWI is used) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1553.6.3 Radial Flow Equation Data (RFLOW) (Skip if WI or PI or WIL or KHWI is used) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1563.6.4 Well Angle Open to Flow (FLOANG) . . . . . . . . . . . . . . . . . . . . . . . . . 3-1583.6.5 Well Datum Depth (WLWDAT) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1593.6.6 Bottomhole Pressure (BHP) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1593.6.7 Tubinghead Pressure (THP) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1603.6.8 Implicit Tubinghead Pressure Equations (IMPTHP) . . . . . . . . . . . . . . 3-1613.6.9 Tubinghead Pressure Iteration Control (ITNTHP) . . . . . . . . . . . . . . . . 3-1613.6.10 Maximum Drawdown Constraint (DPBHMX) . . . . . . . . . . . . . . . . . . 3-162

3.7 Wellbore Crossflow Model . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1633.7.1 Crossflow Option (XFON/XFOFF) (Not available in VIP-THERM) . 3-1633.7.2 Wellbore Gradient Calculation (MBAWG) . . . . . . . . . . . . . . . . . . . . . 3-1643.7.3 Wellbore Gradient Calculation (VIP-THERM) . . . . . . . . . . . . . . . . . . 3-165

3.8 Wellbore Flash Controls . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1663.8.1 THP Convergence Control (BHPITN) . . . . . . . . . . . . . . . . . . . . . . . . 3-166

3.9 Wellbore Hydraulics Tables . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1683.9.1 Wellbore Hydraulics Table Assignment (ITUBE) . . . . . . . . . . . . . . . . 3-1683.9.2 Wellbore Hydraulics Table (BHPTAB) . . . . . . . . . . . . . . . . . . . . . . . . 3-1693.9.3 Wellbore Hydraulics Table Switching (NEWBHPTAB) . . . . . . . . . . . 3-1733.9.4 Wellbore Hydraulics Table for Injectors (BHITAB) . . . . . . . . . . . . . . 3-1753.9.5 Additive Correction to BHP Tables (BHPADD) . . . . . . . . . . . . . . . . . 3-1773.9.6 Artificial Lift Quantity (ALQ) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-177

3.10 Gas Producers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1783.10.1 Assignment of Gas Producer THP Tables (GTHPWL) . . . . . . . . . . . 3-1793.10.2 Gas Well THP Calculation Data (GASTHP) . . . . . . . . . . . . . . . . . . . 3-1793.10.3 Z-factor/Viscosity Tables for Gas Producer THP (THPGTB) . . . . . . 3-180

3.11 Single Phase Injectors . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1823.11.1 Tubing Length Assignment (TUBE) . . . . . . . . . . . . . . . . . . . . . . . . . 3-1823.11.2 Tubing Diameter/Friction Factor (DIAM) . . . . . . . . . . . . . . . . . . . . . 3-1833.11.3 Specify Density and Viscosity Values (WTRTHP) . . . . . . . . . . . . . . 3-183

3.12 Pattern Balancing (Not available in VIP-THERM) . . . . . . . . . . . . . . . . . . . . . . 3-1843.12.1 Pattern Balancing Option (PATTN) . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1843.12.2 Assign Central Injection Wells to a Pattern or Turn Off Pattern Balancing

viii Table of Contents 5000.4.4


(PATNCI ) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1853.12.3 Assign a Peripheral Production Well and Production Fractions to Multiple Patterns (PATNPP) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1873.12.4 Same Perforations in Pattern Gas and Water Injectors (WAGPERF) 3-1883.12.5 Voidage Calculation Based on GOR (PTNGOR) . . . . . . . . . . . . . . . . 3-1893.12.6 Hydrocarbon Volumes and Angles (ATWGVA) . . . . . . . . . . . . . . . . 3-1893.12.7 MI Injection Target and Allocation Parameters (ATWGCL) . . . . . . . 3-1903.12.8 Category Definitions and Injection Fractions (ATWGCT) . . . . . . . . 3-191

3.13 Non-Darcy Gas Flow (Not available in VIP-THERM) . . . . . . . . . . . . . . . . . . . 3-1923.13.1 Non-Darcy Gas Density and Viscosity Option (WNDGDV) . . . . . . . 3-1923.13.2 Specify Rate-Dependent Skin Factors for Non-Darcy Gas Flow (WDNDG) 3-193

3.14 Automatic Recompletion Units . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1943.14.1 Recompletion Unit Status and Limit Data (RCMPPERF) . . . . . . . . . 3-1943.14.2 Order for Opening Recompletion Units (RCMPOR) . . . . . . . . . . . . . 3-197

3.15 WAG (Water-Alternating-Gas) Wells . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1983.15.1 WAG Injection Well Definition (WAG) . . . . . . . . . . . . . . . . . . . . . . 3-1983.15.2 Maximum Rates for WAG Injectors (QMAXWG) . . . . . . . . . . . . . . 3-2013.15.3 Bottomhole Pressure for WAG Injectors (BHPWAG) . . . . . . . . . . . . 3-2023.15.4 Injection Temperature for WAG injectors (TINJWAG, VIP-THERM Only) 3-2033.15.5 Timestep Controls for WAG Injectors (DTWAG) . . . . . . . . . . . . . . . 3-203

3.16 WBSIM (Gridded Wellbore) Well Definition (Not Available in VIP-THERM) . . . . . 3-2043.16.1 WBSIM Well Perforations (COMPERF) . . . . . . . . . . . . . . . . . . . . . . 3-2043.16.2 Dynamic Vertical Flow Transport Parameters Calculation . . . . . . . . 3-207

3.17 Automatic Cycle Control (VIP-THERM) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-2083.17.1 Cycle Tables (CYCLETABLE) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-2083.17.2 Cyclic Well Definition (CYCLIC) . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-2143.17.3 Cycle Phase Perforation Status (CPERF) . . . . . . . . . . . . . . . . . . . . . 3-2143.17.4 Start Cycle (CSTART) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-2163.17.5 Stop Cycle (CSTOP) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-217

3.18 Condensate Banking . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-2183.18.1 Condensate Banking Calculation Parameters (CNDBNK) . . . . . . . . 3-2183.18.2 Selective Application of Condensate Banking (CNDBWL) . . . . . . . 3-219

3.19 Well Index Multipliers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-2213.19.1 Assignment of WI Multiplier Tables (WIMUWL) . . . . . . . . . . . . . . . 3-2213.19.2 WI Multiplier Tables (WIMULTAB) . . . . . . . . . . . . . . . . . . . . . . . . . 3-2213.19.3 Outer Iteration Number (ITNWIMULT) . . . . . . . . . . . . . . . . . . . . . . 3-2223.19.4 Reset Cumulative Reservoir Production (RESETCUM) . . . . . . . . . . 3-223

5000.4.4 Table of Contents ix


Chapter 4Well Management Level Data

4.1 Introduction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-225

4.2 Well Management Levels . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-2254.2.1 Well Management Level Definition (GATHER, FLOSTA, AREA) . . 4-2254.2.2 Fraction of Time Management Level is Onstream (ONTIME) . . . . . . 4-226

4.3 Production and Injection Targeting . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-2284.3.1 Production Target (PTARG) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-2284.3.2 Production Target History Option (PTARGH) . . . . . . . . . . . . . . . . . . . 4-2304.3.3 Production Target Frequency (PTGFRQ) . . . . . . . . . . . . . . . . . . . . . . . 4-2314.3.4 Options for Reduction of Rates to Meet Target (TRGOPT) . . . . . . . . 4-2324.3.5 Order for Checking Phase Targets (TRGORD) . . . . . . . . . . . . . . . . . . 4-2354.3.6 Minimum Rate for Use in Targeting Calculations (TRGQMN) . . . . . . 4-2374.3.7 Well Rate Maximum Tolerances (TRGTOL) . . . . . . . . . . . . . . . . . . . . 4-2384.3.8 Injection Target (ITARG) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-2394.3.9 Well Rate Scaleback Options with Targeting (LSCALE) . . . . . . . . . . 4-240

4.4 Minimum Rates . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-2424.4.1 Minimum Production Rates (PRDMIN) . . . . . . . . . . . . . . . . . . . . . . . . 4-2424.4.2 Minimum Injection Rates (INJMIN) . . . . . . . . . . . . . . . . . . . . . . . . . . 4-243

4.5 Gas Cycling (Not available in VIP-THERM) . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-2454.5.1 Shrinkage Gas Specification (GASSKG) . . . . . . . . . . . . . . . . . . . . . . . 4-2454.5.2 Fuel Gas Specification (GASFUL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-2464.5.3 Sales Gas Specification (GASSLS) . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-2484.5.4 Makeup Gas Specification (GASMKP) . . . . . . . . . . . . . . . . . . . . . . . . 4-2494.5.5 Makeup MI Specification (MIMKP) . . . . . . . . . . . . . . . . . . . . . . . . . . 4-2514.5.6 Effective Gas Injection Target (ETRGOP) . . . . . . . . . . . . . . . . . . . . . . 4-2524.5.7 Makeup Gas Composition (YINJMK) . . . . . . . . . . . . . . . . . . . . . . . . . 4-2534.5.8 Reinjected Gas Composition (YREINJ) . . . . . . . . . . . . . . . . . . . . . . . . 4-2544.5.9 Reinjection Gas Composition When Zero Production (YZERO) . . . . 4-2564.5.10 Liquid Recovery Factors (RECFAC) . . . . . . . . . . . . . . . . . . . . . . . . . 4-2584.5.11 Invoke Major Gas Sales Option (PLANT) . . . . . . . . . . . . . . . . . . . . . 4-2594.5.12 Gas Conditioning for Sales Gas and Fuel Gas (GASCOND) . . . . . . . 4-2604.5.13 Natural Gas Liquid (NGL) Plant Data Input (NGLPLANT) . . . . . . . 4-2614.5.14 Miscible Injectant (MI) Plant Data Input (MIPLANT) . . . . . . . . . . . 4-2644.5.15 Liquified Petroleum Gas (LPG) Plant Data Input (LPGPLANT) . . . 4-2674.5.16 Maximum Feed Rate to NGL Plant (NGLFED) . . . . . . . . . . . . . . . . . 4-2694.5.17 Maximum NGL Rate (NGLOUT) . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-2704.5.18 Maximum Feed Rate to LPG Plant (LPGFED) . . . . . . . . . . . . . . . . . 4-2714.5.19 Maximum LPG Rate (LPGOUT) . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-272

4.6 Basic Gas Reinjection (GINJOP) (Not Available in VIP-THERM) . . . . . . . . . . 4-273

4.7 Injection Regions (Not available in VIP-THERM) . . . . . . . . . . . . . . . . . . . . . . . 4-2744.7.1 Define the Injection Region Option (RINJOP) . . . . . . . . . . . . . . . . . . . 4-2744.7.2 Assign Name to Injection Region (INJRNM) . . . . . . . . . . . . . . . . . . . 4-276

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4.7.3 Maximum Source Water Injection Rate (IRSRCW) . . . . . . . . . . . . . . 4-2764.7.4 Assign Injection Wells to Injection Regions (INJRGR) . . . . . . . . . . . . 4-2774.7.5 Distribution Percentage of Injection Rate to Injection Regions (IRPCTA) . 4-2784.7.6 Assign Gridblocks to Injection Regions (INJREGN) . . . . . . . . . . . . . . 4-2784.7.7 Specify How Distribution of Injection Fluid is to Occur (IRDIST) . . . 4-2794.7.8 Forced Gas Injection Into Injection Regions (IRGAS) . . . . . . . . . . . . 4-2824.7.9 Select Gas Project Prioritization Option (PRIOP) . . . . . . . . . . . . . . . . 4-2854.7.10 Assign Name to Gas Project (PROJNM) . . . . . . . . . . . . . . . . . . . . . . 4-2854.7.11 Assign Gas Injection Wells to Projects (PROJWL) . . . . . . . . . . . . . . 4-2864.7.12 Prioritize Gas Projects (PRIIR) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-286

4.8 Voidage Injection by Guide Rate (Not available in VIP-THERM) . . . . . . . . . . . 4-2874.8.1 Maximum Injection Target for a Group (INJTAR) . . . . . . . . . . . . . . . 4-2874.8.2 Injection Guide Rate for a Group (INJGR) . . . . . . . . . . . . . . . . . . . . . 4-289

4.9 Water Injection Pumps (Not available in VIP-THERM) . . . . . . . . . . . . . . . . . . . 4-2904.9.1 Assign Injector Pump Characteristics Tables (IPUMP) . . . . . . . . . . . . 4-2904.9.2 Water Injection Pump Discharge Pressure (PMPTAB) . . . . . . . . . . . . 4-2914.9.3 Convergence Criteria (WTRPUMP) . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-291

4.10 Gaslift . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-2934.10.1 Gaslift Allocation (QLIFT) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-2934.10.2 Gaslift Gas Source (QLIFTA) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-2954.10.3 Optimal GLR Tables for Gaslift (GLRTAB) . . . . . . . . . . . . . . . . . . . 4-2974.10.4 Optimal GLR Table Pointer for Gaslift (GLRTBP) . . . . . . . . . . . . . . 4-2984.10.5 Maximum Well Gaslift Gas Rate (GLGMAX) . . . . . . . . . . . . . . . . . 4-2994.10.6 Minimum Well Gaslift Gas Rate (GLGMIN) . . . . . . . . . . . . . . . . . . . 4-3004.10.7 Additive Correction to GLR Tables (GLRADD) . . . . . . . . . . . . . . . . 4-3014.10.8 Time Interval for Gaslift Gas Rate Calculations (TESTGL) . . . . . . . 4-3024.10.9 Minimum Gaslift Efficiency (GLEFMN) . . . . . . . . . . . . . . . . . . . . . . 4-3024.10.10 Performance Curve Option Data (PFMCRV) . . . . . . . . . . . . . . . . . . 4-3024.10.11 Gaslift Gas in Gas Handling Loop (GLGOP) . . . . . . . . . . . . . . . . . . 4-3054.10.12 Makeup Gaslift Gas Specification (QLIFTM) . . . . . . . . . . . . . . . . . 4-306

4.11 Multi-level Optimization of Gaslift Gas Utilization . . . . . . . . . . . . . . . . . . . . . 4-3074.11.1 Introduction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-3074.11.2 Specifications . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-3074.11.3 Gaslift Optimization Outer Iteration Number (ITNGLG) . . . . . . . . . 4-308

4.12 Automatic Drilling Option . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-3094.12.1 Drilling Rig Definition (DRLRIG) . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-3094.12.2 List of Wells in Drilling Queues (DRILLQUEUE) . . . . . . . . . . . . . . 4-3104.12.3 Target Specification (DRLTRG) . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-3134.12.4 Drilling of Replacement Wells (DRILLWELL) . . . . . . . . . . . . . . . . . 4-3154.12.5 Elapsed Time to Drill a Well (WLDRTIME) . . . . . . . . . . . . . . . . . . . 4-318

4.13 Automatic Well Workovers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-3204.13.1 Workover Rig Definition (WRKRIG) . . . . . . . . . . . . . . . . . . . . . . . . 4-320

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4.13.2 Relative Number of Workovers (WRKRTO) . . . . . . . . . . . . . . . . . . . 4-3214.13.3 Workover Calculation Frequency (WRKFRQ) . . . . . . . . . . . . . . . . . 4-3224.13.4 Elapsed Time Between Workovers (WRKDLT) . . . . . . . . . . . . . . . . 4-3234.13.5 Workover Failure Rate (WRKFAIL) . . . . . . . . . . . . . . . . . . . . . . . . . 4-3244.13.6 Well Limit for Automatic Shutoffs (WRKWLM) . . . . . . . . . . . . . . . 4-3244.13.7 Workover Benefit Function Limits (WRKLIM) . . . . . . . . . . . . . . . . 4-3254.13.8 Group Numbers for "Group 1" (WRKGP1) . . . . . . . . . . . . . . . . . . . . 4-3274.13.9 Group Numbers for "Group 2" (WRKGP2) . . . . . . . . . . . . . . . . . . . . 4-3294.13.10 “Group 1” Default Coefficients (WRKCF1) . . . . . . . . . . . . . . . . . . 4-3304.13.11 “Group 2” Default Coefficients (WRKCF2) . . . . . . . . . . . . . . . . . . 4-3314.13.12 Coefficients for Workover Benefit Functions (WRKCOEF) . . . . . . 4-3324.13.13 Debug Output (WRKDBG) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-334

4.14 Fluid Tracking (Not available in VIP-THERM) . . . . . . . . . . . . . . . . . . . . . . . . 4-3354.14.1 Fluid Tracking Option (TRACK) . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-3354.14.2 Tracked Fluid Number (YINJT) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-3364.14.3 Activates Tracked Fluid Composition Output (OPRSYS) . . . . . . . . . 4-336

4.15 Water Tracking (Not available in VIP-THERM) . . . . . . . . . . . . . . . . . . . . . . . 4-3384.15.1 Tracked Water Mixing Parameter (FTWMIX) . . . . . . . . . . . . . . . . . . 4-3384.15.2 Tracked Water Type Number (WINJT) . . . . . . . . . . . . . . . . . . . . . . . 4-338

Chapter 5Predictive Well Management

5.1 Introduction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-339

5.2 Keywords Common to NEW PWM and MGOR PWM . . . . . . . . . . . . . . . . . . . 5-3405.2.1 Predictive Well Management (PREDICT) . . . . . . . . . . . . . . . . . . . . . . 5-3405.2.2 Number of Outer Iterations Each Timestep (WMITN) . . . . . . . . . . . . 5-3405.2.3 Pressure Systems and Lift Methods Available (PWMGC) . . . . . . . . . 5-3415.2.4 Tubinghead Pressure (THP) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-3425.2.5 Production Target Data (PTARG) . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-3425.2.6 Frequency of PWM Calculations (PWMFRQ) . . . . . . . . . . . . . . . . . . . 5-3455.2.7 Bottomhole Pressure Tables (SYSTB) . . . . . . . . . . . . . . . . . . . . . . . . . 5-3455.2.8 Define Pressure Systems for Wells During History (HISTSYS) . . . . . 5-3465.2.9 Defining Pressure Systems (PRSYS) . . . . . . . . . . . . . . . . . . . . . . . . . . 5-3475.2.10 Artificial Lift Method Names (ARTLFT) . . . . . . . . . . . . . . . . . . . . . 5-3485.2.11 Tolerance for Production Rates (PWMTLP, NONPWM, TRGPWM) . . 5-3485.2.12 Oil Incremental Benefit with Gaslift (PWMOBN) . . . . . . . . . . . . . . . 5-3505.2.13 Maximum PWM Timestep Size (DTPWM) . . . . . . . . . . . . . . . . . . . . 5-3505.2.14 Write PWM Report to File (PWMFILE) . . . . . . . . . . . . . . . . . . . . . . 5-3515.2.15 Debug Output (PWMDBG) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-351

5.3 Keywords for NEW PWM . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-3535.3.1 Minimum Oil Rate for Producers (QOMIN) . . . . . . . . . . . . . . . . . . . . 5-3535.3.2 Minimum Gas Rate for Producers (QGMIN) . . . . . . . . . . . . . . . . . . . . 5-3545.3.3 PWM Calculation Steps (PWMSTEP) . . . . . . . . . . . . . . . . . . . . . . . . . 5-356

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5.3.4 Producing Area Number (PWMWPA) . . . . . . . . . . . . . . . . . . . . . . . . . 5-3625.3.5 Producing Mechanism (PWMWPM) . . . . . . . . . . . . . . . . . . . . . . . . . . 5-3635.3.6 Define Well Category (PWMCAT) . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-3645.3.7 MUSTFLOW Well Specification (MUSTFLOW) . . . . . . . . . . . . . . . . 5-3655.3.8 Minimum Oil Rate for Wells on Gaslift (QOMINL) . . . . . . . . . . . . . . 5-3655.3.9 Execute Normal Targeting Procedure (PWMTRG) . . . . . . . . . . . . . . . 5-3675.3.10 Frequency of Pressure System Switching (PRSDLT) . . . . . . . . . . . . 5-3675.3.11 Well Rate Control (PWMWCN) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-367

5.4 Keywords for MGOR PWM . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-3695.4.1 Separator Battery Numbers (SYSSEP) . . . . . . . . . . . . . . . . . . . . . . . . . 5-3695.4.2 MGOR Option Data (PRMGOR) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-3695.4.3 Water-Cut Versus Efficiency Table (EFFTAB) . . . . . . . . . . . . . . . . . . 5-3705.4.4 Specify Wells Included in Well Debug Report (WPWMDB) . . . . . . . 5-371

Chapter 6Output Control

6.1 Introduction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-373

6.2 Print/Map Arrays and Parameters (OUTPUT, MAPOUT) . . . . . . . . . . . . . . . . . 6-374

6.3 Array Print Windows (OUTWINDOW) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-383

6.4 Content and Frequency of Printed Output (PRINT) . . . . . . . . . . . . . . . . . . . . . . 6-385

6.5 Buildup Pressure Output Control (BUILDUP) . . . . . . . . . . . . . . . . . . . . . . . . . . 6-390

6.6 Write Files (WPLOT, WMAP, WMAPOLD, WREST, WFLUX, WFILE, WCPLOT) 6-391

6.7 Save Temporary Restarts (WLASTR) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-393

6.8 Write Fluid Tracking Data (WTRACK) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-393

6.9 Print/Map Mole Fractions (OUTX, OUTY, OUTZ, OUTXT, OUTYT, OUTZT, MAPX, MAPY, MAPZ, MAPXT, MAPYT, MAPZT) . . . . . . . . . . . . . . . . . . . . . . 6-395

6.10 Format of Mole Fraction Array Print (ALLCOMP) . . . . . . . . . . . . . . . . . . . . . 6-396

6.11 Tracked Water Type Fractions (OUTWT, MAPWT) . . . . . . . . . . . . . . . . . . . . 6-396

6.12 Specify Which Separator Batteries to Process (OUTSEP) . . . . . . . . . . . . . . . . 6-397

6.13 Reservoir Region Separator Battery Assignment (REGSEP) . . . . . . . . . . . . . . 6-398

6.14 Compute Potentials for Plot File (PLOTPTN) . . . . . . . . . . . . . . . . . . . . . . . . . 6-399

6.15 Printout Processed Well Cards (PRINTOUT) . . . . . . . . . . . . . . . . . . . . . . . . . . 6-399

6.16 Logical Unit for Timestep Summary Output (IPRTSS) . . . . . . . . . . . . . . . . . . 6-400

6.17 Specify Wells Included in Well RFT Report (OUTRFT) . . . . . . . . . . . . . . . . . 6-400

6.18 Spreadsheet Files (SSSUM) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-401

6.19 Well Average Pressure Calculation (OUTPAVG) . . . . . . . . . . . . . . . . . . . . . . 6-410

5000.4.4 Table of Contents xiii


6.20 Print Well Indices (PRWI) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-412

6.21 Print Well Properties Summary (PRWSTA) . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-412

6.22 Track File Format (TFORM) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-412

6.23 Boundary Flux File Format (FXFORM) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-413

6.24 Print by Cross-Sections (CROSS) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-413

6.25 Grouping Wells (WLGRP) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-414

6.26 Group Specification of Maximum Well Rates (QMAXGR) . . . . . . . . . . . . . . . 6-415

6.27 Plot File Well Specification (PLOTLIST) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-415

6.28 Spreadsheet Well Specification (SPRLIST) . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-417

6.29 Saturation Endpoint Debug Report (SATDEBUG) . . . . . . . . . . . . . . . . . . . . . . 6-419

6.30 Results File Formats . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-4206.30.1 Plot File Organization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-4206.30.2 Compositional Plot File Organization . . . . . . . . . . . . . . . . . . . . . . . . 6-4246.30.3 Map File Organization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-4286.30.4 Hydrocarbon Track File Organization . . . . . . . . . . . . . . . . . . . . . . . . 6-431

Chapter 7Simulator Control

7.1 Timestep Control . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-4337.1.1 Timestep Controls (DT) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-4347.1.2 Timestep Size After Rate Changes (DTQMAX) . . . . . . . . . . . . . . . . . 7-4367.1.3 Outer Iteration Controls (ITNLIM) . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-4377.1.4 Control Convergence Failures and Timestep Cuts (TCUT) . . . . . . . . . 7-4387.1.5 Control Treatment of IMPES Stability (IMPSTAB) . . . . . . . . . . . . . . 7-4397.1.6 Maximum Variable Change Overshoot (MAXOVR) . . . . . . . . . . . . . . 7-4407.1.7 Convergence Tolerance on Unknowns (TOLD) . . . . . . . . . . . . . . . . . . 7-4417.1.8 Convergence Tolerance on Residuals (TOLR) . . . . . . . . . . . . . . . . . . . 7-4427.1.9 Saturation Convergence Tolerance for OPTMBL and VOLBAL (TOLSCN) 7-4437.1.10 Well Convergence Tolerance for OPTMBL and VOLBAL (TOLWCN) 7-4447.1.11 Maximum Allowable Material Balance Error (ABORT) . . . . . . . . . . 7-4447.1.12 Minimum BHP Damping Factor (CBHPMN) . . . . . . . . . . . . . . . . . . 7-4457.1.13 Table Extrapolation Control (CHKTAB) . . . . . . . . . . . . . . . . . . . . . . 7-4457.1.14 Timestep Size Factors (MXDTCF, MXDTFC, DTCUTF) . . . . . . . . 7-446

7.2 Matrix Solution Options . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-4477.2.1 Gaussian Elimination (GAUSS) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-4487.2.2 Iterative Solver (EXCEL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-4487.2.3 Iterative Solver (BLITZ) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-4497.2.4 Bad Solution Indicator (SLVCUT) . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-452

xiv Table of Contents 5000.4.4


7.3 Implicit Well Options . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-4537.3.1 Implicit Well Calculations in IMPES Grids (IMPWEL) . . . . . . . . . . . 7-453

7.4 Automatic Parameter Settings (FASTSIM) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-454

7.5 Interactive Suspend Option . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-4567.5.1 Interactive Card (INTERACTIVE) . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-4577.5.2 BATCH Card (BATCH) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-458

7.6 Interactive Recurrent Data Changes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-459

Chapter 8Miscellaneous Options

8.1 Energy Minimization Phase Equilibrium (VIP-COMP) . . . . . . . . . . . . . . . . . . . 8-4618.1.1 Invoking the Gibbs Algorithm (GIBBS) . . . . . . . . . . . . . . . . . . . . . . . 8-4618.1.2 Turning Off the Gibbs Algorithm (GIBOFF) . . . . . . . . . . . . . . . . . . . . 8-463

8.2 Successive Substitution Flash Data (VIP-COMP) . . . . . . . . . . . . . . . . . . . . . . . . 8-4638.2.1 Definition of Flash Calculation Method (FLASH) . . . . . . . . . . . . . . . . 8-4638.2.2 Control of Flash Calculations (KMAX) . . . . . . . . . . . . . . . . . . . . . . . . 8-464

8.3 Gas Percolation Algorithm (GASPERC) (Not available in VIP-THERM) . . . . . 8-466

8.4 Gas Remobilization Option (GASRMON) (Not available in VIP-THERM) . . . 8-466

8.5 Modified Land’s Constant for Hysteresis (MODLAND) . . . . . . . . . . . . . . . . . . 8-468

8.6 Modifying VIP-CORE Array Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8-4698.6.1 Override Modification (OVER) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8-4698.6.2 Override Modification, VIP-DUAL (OVER) . . . . . . . . . . . . . . . . . . . . 8-4718.6.3 Individual Value Override Modification (VOVER) . . . . . . . . . . . . . . . 8-4728.6.4 Individual Value Override Modification, VIP-DUAL (VOVER) . . . . 8-4748.6.5 Modifying Fault Connection Transmissibilities (FTRANS) . . . . . . . . 8-4768.6.6 Modifying Fault Connection Transmissibilities, VIP-DUAL (FTRANF) . 8-477

8.7 Named Fault/Region Transmissibility Multiplier (MULTFL) . . . . . . . . . . . . . . 8-478

8.8 Inter/Intra Region Transmissibility Multiplier (MULTIR) . . . . . . . . . . . . . . . . . 8-478

8.9 Pressure Threshold for Limiting Grid Block to Grid Block Flow (PTHLD) . . . 8-479

8.10 Phase Identification (PHASID) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8-481

8.11 Diffusion Activation/Deactivation (DIFFUSION) . . . . . . . . . . . . . . . . . . . . . . 8-482

Chapter 9Polymer Option (VIP-POLYMER)

9.1 Polymer Physical Property Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9-4839.1.1 Change Default Dimensions (DIM) . . . . . . . . . . . . . . . . . . . . . . . . . . . 9-4839.1.2 Polymer Mode (POLYMER) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9-4849.1.3 Polymer Concentration/Salinity Table (POLYT) . . . . . . . . . . . . . . . . . 9-484

5000.4.4 Table of Contents xv


9.1.4 Polymer Concentration/Salinity Functions (POLYF) . . . . . . . . . . . . . . 9-4869.1.5 Non-Newtonian Viscosity Cards (SHEAR) . . . . . . . . . . . . . . . . . . . . . 9-4879.1.6 Polymer Inaccessible Pore Volume Card (EPHIP) . . . . . . . . . . . . . . . . 9-4899.1.7 Cation Exchange Cards (IONEX) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9-4899.1.8 Effective Divalent Salinity Cards (CSEP) . . . . . . . . . . . . . . . . . . . . . . 9-4909.1.9 Salinity Units Card (SUNITS) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9-490

9.2 Injectors . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9-4919.2.1 Polymer Concentration (CPINJ) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9-4919.2.2 Anion (Chloride) Concentration (CLINJ) . . . . . . . . . . . . . . . . . . . . . . . 9-4919.2.3 Divalent Cation (Calcium) Concentration (CAINJ) . . . . . . . . . . . . . . . 9-4929.2.4 Polymer Slug Definition (PSLUG) . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9-4929.2.5 Describe Well Perforations (FPERF) . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9-493

9.3 Instantaneous Gel Model . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9-4939.3.1 Gel Data (GEL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9-4939.3.2 Permeability Reduction Multiplier (RKMULT) . . . . . . . . . . . . . . . . . . 9-494

9.4 Print/Map Arrays and Parameters (OUTPUT, MAPOUT) . . . . . . . . . . . . . . . . . 9-494

9.5 Timestep Controls (DT) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9-496

9.6 Modifying VIP-CORE Array Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9-4979.6.1 Override Modification (OVER) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9-4979.6.2 Individual Value Override Modification (VOVER) . . . . . . . . . . . . . . . 9-497

Chapter 10

Surface Pipeline Network Option

10.1 General Information . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-499

10.2 Flow Modeling in Well Tubing Strings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-502

10.3 Application of Hydraulic Tables for Modeling Flow in Flow Devices . . . . . . 10-503

10.4 Application of Look-Up Tables for Pressure Gradient Determination in Pipes . . 10-503

10.5 Profiles of Temperature, Inclination Angle, Valve Coefficient, Choke Correlation, and PVT Tables (CURVE) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-504

10.5.1 Temperature Profile (CURVE TEMPPR) . . . . . . . . . . . . . . . . . . . . 10-50410.5.2 Temperature Gradient Profile (CURVE TMGRPR) . . . . . . . . . . . . 10-50510.5.3 Elevation Profile (CURVE ELEVPR) . . . . . . . . . . . . . . . . . . . . . . . 10-50610.5.4 Valve Coefficient Profile (CURVE VCPR) . . . . . . . . . . . . . . . . . . . 10-50710.5.5 Choke Correlation (CURVE IDPR) . . . . . . . . . . . . . . . . . . . . . . . . . 10-50810.5.6 PVT Property Table Profile (CURVE IPVTPR) . . . . . . . . . . . . . . . 10-509

10.6 Pipe Data (PIPES) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-510

10.7 Tubing Data (TUBING) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-514

10.8 Valve Data (VALVES, VALSET) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-518

xvi Table of Contents 5000.4.4


10.9 Link Data (LINK) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-522

10.10 Node Data (NODES) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-52610.10.1 Gas Partial Processing Optimization (PPOPT) . . . . . . . . . . . . . . . . 10-530

10.11 Node Connection Data (NODCON) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-532

10.12 Lift Gas Composition (YINJA) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-535

10.13 Well Connection Data (WELCON) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-536

10.14 Satellite Field Production Data (NODSOURCE and SOUCOM) . . . . . . . . . 10-541

10.15 Production Fluids from Different PVT Units . . . . . . . . . . . . . . . . . . . . . . . . 10-54310.15.1 Water PVT Profile (SPNPVW) . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-54310.15.2 Surface Network PVT Unit (SPNPVT) . . . . . . . . . . . . . . . . . . . . . 10-54410.15.3 Well PVT Unit (SPNPTU) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-54510.15.4 Describe Well Perforations (FPERF) . . . . . . . . . . . . . . . . . . . . . . . 10-545

10.16 Pseudo Well Option . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-54610.16.1 Inflow Performance Correlations (BHITAB) . . . . . . . . . . . . . . . . . 10-54710.16.2 Correlation Assignments (PSEUTAB) . . . . . . . . . . . . . . . . . . . . . . 10-55010.16.3 Reservoir Pressure (PSEUPRES) . . . . . . . . . . . . . . . . . . . . . . . . . . 10-55110.16.4 Compositions (PSEUXY) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-55110.16.5 Well Status (PSEUWS) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-552

10.17 General Parameters of the Surface Pipeline Network System (NETPAR) . . 10-554

10.18 Output of Surface Pipeline Network Information . . . . . . . . . . . . . . . . . . . . . 10-55910.18.1 Node Report in Print File . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-55910.18.2 Node Spreadsheet File (SSSUM) . . . . . . . . . . . . . . . . . . . . . . . . . . 10-56010.18.3 Spreadsheet Node Specification (SPRLIST) . . . . . . . . . . . . . . . . . 10-56210.18.4 Tubing Report . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-56310.18.5 Surface Pipeline Network Information in Plot File . . . . . . . . . . . . 10-56410.18.6 Generation of Hydraulic Tables (HTOUTPUT) . . . . . . . . . . . . . . . 10-564

10.19 Production Well Optimization Option . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-57110.19.1 Default Dimensions (DIM) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-57110.19.2 Objective Coefficients (OBJCOEF) . . . . . . . . . . . . . . . . . . . . . . . . 10-57110.19.3 Lock Well Rates (LOCK) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-57210.19.4 Surface Network Optimization Control (NTOPTC) . . . . . . . . . . . . 10-57310.19.5 Node Data (NODES) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-57410.19.6 Well Connection Data (WELCON) . . . . . . . . . . . . . . . . . . . . . . . . 10-57510.19.7 Maximum Velocity Constraints (WLVEL) . . . . . . . . . . . . . . . . . . 10-57610.19.8 Output Well and Node Connection Changes (PRTSWT) . . . . . . . 10-57610.19.9 Gaslift Optimization Using Performance Curves (PFMCRV) . . . . 10-577

10.20 Integration of Surface Pipeline Network and Predictive Well Management . 10-57810.20.1 Number of Outer Iterations Each Timestep (WMITN) . . . . . . . . . 10-578

10.21 Understanding Injection Network Allocations and Node Pressures in VIP . 10-58010.21.1 Examples . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-582

10.1.0.1 Injection Network with No Group Targeting . . . . . . . . . . 10-583

5000.4.4 Table of Contents xvii


10.1.0.2 Injection Network with Group Targeting Using ITARG . . 10-58410.1.0.3 Injection Regions for Group Targets . . . . . . . . . . . . . . . . . 10-58510.1.0.4 Injection Regions with Network Node Targets . . . . . . . . . 10-586

10.21.2 Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-586

Chapter 11Automatic Tuning Procedures

11.1 General Information . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11-587

11.2 Well Index Adjustment Procedure (WIADJ) and Tubing String Parameter Adjustment Procedure (TBADJ). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11-587

11.3 Dynamic TUNING Procedure . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11-59511.3.1 General Parameters (TUNING, ENDTUNING) . . . . . . . . . . . . . . . . 11-60011.3.2 Convergence Tolerances (MAXRER and MAXRNE) . . . . . . . . . . 11-60211.3.3 Parameter Ranges (TWELL, TFPERF, TTUBING, TWLFL, TSPN, MNPF-CF, MNFLCF) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11-60411.3.4 Activation of Inactive Perforations (MINRER) . . . . . . . . . . . . . . . . 11-60711.3.5 Field Measurements and Error Function Coefficients (QMULT, TBHP, TTHP, TPRND, TERC) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11-60911.3.6 Adjustment Factors (ADJWI, ADJFPERF, ADJTUBING, ADJWLFL, AD-JSPN) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11-61111.3.7 Output of Automatic Tuning Results . . . . . . . . . . . . . . . . . . . . . . . . 11-613

Chapter 12Gas Field Operations (GFO) Option

12.1 Introduction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12-615

12.2 Gas Field Operations Data (GFO) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12-616

12.3 Annual Scheduling File (ASF) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12-621

Chapter 13Local Grid Refinement

13.1 Introduction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13-623

13.2 Formulation Options . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13-62313.2.1 Formulation Specification by Grid (IMPGRID) (VIP-COMP or VIP-EN-CORE) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13-62313.2.2 Turn Off Pressure Interpolation (NOPINT) . . . . . . . . . . . . . . . . . . . 13-624

13.3 Activate/Deactivate Grids (Not available in VIP-THERM) . . . . . . . . . . . . . . 13-625

13.4 Timestep Controls . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13-62613.4.1 Timestep Controls for IMPLICIT Grids (DTMPL) (VIP-COMP or VIP-EN-CORE) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13-62613.4.2 Iteration Controls for IMPLICIT Grids (ITNMPL) (VIP-COMP or VIP-EN-CORE) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13-627

xviii Table of Contents 5000.4.4


13.5 Matrix Solution Option (CBLITZ) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13-62813.5.1 CBLITZ Parameters by Grid (CBLGRID) . . . . . . . . . . . . . . . . . . . . 13-630

13.6 Well Data Options . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13-63213.6.1 Well Name and Location (WELL) . . . . . . . . . . . . . . . . . . . . . . . . . . 13-63213.6.2 Describe Well Perforations (FPERF) . . . . . . . . . . . . . . . . . . . . . . . . 13-632

13.7 Assign Gridblocks to Injection Regions (INJREGN) . . . . . . . . . . . . . . . . . . . 13-634

13.8 Options Restricted to Use with Single-Grid Systems Only . . . . . . . . . . . . . . . 13-634

13.9 Arbitrary Gridblock Connections (FTRANS) . . . . . . . . . . . . . . . . . . . . . . . . . 13-634

13.10 Override Modification (OVER) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13-635

13.11 Value Override (VOVER) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13-635

Chapter 14Tracer Option

14.1 Introduction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14-637

14.2 VIP Tracer Option Input Data Description . . . . . . . . . . . . . . . . . . . . . . . . . . . 14-63714.2.1 Change Default Dimensions (DIM) . . . . . . . . . . . . . . . . . . . . . . . . . 14-63814.2.2 Activate Front Tracking Option (FRONT) . . . . . . . . . . . . . . . . . . . . 14-63814.2.3 Define Parameters for Tracer Option (TRACER) . . . . . . . . . . . . . . 14-63914.2.4 Inject Tracer (TRACIN) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14-64114.2.5 Write Map Records to Database (WTRACE) . . . . . . . . . . . . . . . . . . 14-64314.2.6 Write Plot Records to Database (WTRPLOT) . . . . . . . . . . . . . . . . . 14-64314.2.7 Write Records to Tracer File (WTRDBG) . . . . . . . . . . . . . . . . . . . . 14-64414.2.8 Write Tracer Summary (PRINT TRACER) . . . . . . . . . . . . . . . . . . . 14-645

Chapter 15Parallel Computing

15.1 Parallel Grid Assignment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15-64715.1.1 Introduction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15-64715.1.1 Processor Mapping File . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15-647

Chapter 16RESOLVE® Control of VIP Simulation

16.1 Turn On RESOLVE® Control of VIP Simulation (RESOLVE) . . . . . . . . . . 16-651

Appendix vReferencesKeyword IndexSubject Index

5000.4.4 Table of Contents xix


xx Table of Contents 5000.4.4

Preface

v

000000About This Manual

Introduction

VIP-COMP®, VIP-ENCORE®, VIP-DUAL®, VIP-POLYMER®, and VIP-

THERM® are the simulation modules of the VIP-EXECUTIVE® Family of simulators. The VIP-COMP, VIP-ENCORE, VIP-DUAL, and VIP-POLYMER modules are all conveniently "packaged" within a single program library which we call VIP-EXECUTIVE. 00

Purpose

The primary purpose of this Reference Manual is to document the input options of the VIP-EXECUTIVE suite of reservoir simulation modules. It is assumed that the reader is familiar with reservoir engineering concepts, in general, and reservoir simulation terminology, specifically. This document is not intended to be a cookbook for the novice simulation user. 00

The Modules

This manual is intended to be used in conjunction with the VIP-CORE Reference Manual. VIP-CORE is the module within VIP-EXECUTIVE which calculates the initial reservoir conditions to be used by one of the simulation modules. 00

The VIP-EXECUTIVE reservoir simulator contains the following program modules: 00

VIP-ENCORE Multi-Component Black-Oil Model

VIP-COMP Equation-of-State Compositional Model

VIP-DUAL Dual-Porosity Model

VIP-POLYMER Polymer Flooding Model

VIP-THERM Thermal Model

These program modules work together to provide total flexibility in reservoir modeling. For example, VIP-ENCORE and VIP-DUAL could be combined to

5000.4.4 xxi


provide simulation capability for a dual-porosity, black-oil reservoir. If VIP-COMP were included in the same program, the user could convert to a fully compositional version of the dual-porosity model simply by substituting the compositional specific data for the black-oil specific data.00

The Chapters

The input data stream for the simulation modules consists of keywords and data values which invoke the features of the simulator. Chapter 1 is an overview of the data; it also describes data cards which are used throughout the entire data stream. The subsequent chapters describe the time-dependent data, which have some order dependencies. (Any restrictions are described in the appropriate section. 00

Data Format

The keywords, or alpha labels, used in the data input stream are denoted in this manual by upper case letters. The names of the variables that are entered as numbers in the data stream are typed in lower case letters. 00

Data Options

In all of the data descriptions, parentheses are used to indicate optional items of data. Parentheses are never included in the actual data stream, unless specifically noted. Items of data that are aligned vertically in the description of a single data card indicate a choice. The items are mutually exclusive. 00

Compatibility

This documentation is compatible with Version 5000.4.4 of the VIP-EXECUTIVE software. Along with additional enhancements, some of the formats have been modified. In the case of changed formats, only our new formats appear. 00

Units

Internal calculations are carried out in customary oil field units, but input and output can be in either customary units or the International System of Units (SI) metric system or in laboratory units. Throughout this Reference Manual, units are first listed as the customary units followed by the SI units in parentheses. The user

may choose metric pressure units of kg/cm2 (bar) instead of the default kPa. In

this case, whenever the documentation reads kPa, kg/cm2 (bar) will be expected. A table of data types and the possible units is given in Section 1.7. 00

xxii 5000.4.4


Related Documentation

The following manuals provide more information related to the material in this manual. For more information, please consult the appropriate manual listed below.00

n VIP-EXECUTIVE Technical Reference. A detailed discussion of the mathematical theory behind the VIP simulators. [Available only in hardcopy]

n VIP-CORE Reference Manual. A complete summary of all keywords and data formats needed to build an initial reservoir model.

5000.4.4 xxiii


xxiv 5000.4.4

Chapter

1

00000Data Overview

1.1 Introduction

VIP-COMP®, VIP-ENCORE®, VIP-DUAL®, VIP-POLYMER®, and VIP-THERM® are the simulation modules of the VIP-EXECUTIVE® Family of simulators. The VIP-COMP, VIP-ENCORE, VIP-DUAL, VIP-POLYMER, and VIP-THERM modules are all conveniently “packaged” within a single program library which we call VIP-EXECUTIVE. When VIP-DUAL is executed, it is used in conjunction with either VIP-COMP or VIP-ENCORE. For example, VIP-CORE, VIP-ENCORE and VIP-DUAL may be combined to provide a modeling capability for a fractured “black-oil” reservoir. If VIP-COMP replaces VIP-ENCORE, the user could convert to a fully compositional version of the fractured reservoir model simply by substituting the compositional specific data for the black-oil specific data. All of these modules contain one or more of our newest solution algorithms: EXCEL and BLITZ.

Only the particular modules purchased are activated. These are listed on the first page of computer output in the title box.

The documentation for VIP-COMP, VIP-ENCORE, VIP-DUAL, VIP-POLYMER, and VIP-THERM are included in this Reference Manual. The major features are applicable to all of the modules; therefore, the majority of the data required for all four of these modules is identical. Where data differs between VIP-COMP, VIP-ENCORE, and VIP-THERM or additional data is required for VIP-DUAL, VIP-POLYMER, or VIP-THERM, the model to which the described data applies is enclosed in parentheses after the section heading.

1.1.1 VIP-COMP Overview

VIP-COMP is an n-component, equation-of-state, compositional simulator. It can simulate the flow of oil, gas, and water through an underground reservoir and predict the behavior of all associated production/injection wells. The system takes into account the fact that fluid properties and phase behavior can vary strongly with fluid composition. Fluid properties and phase equilibrium are governed by generalized cubic equation-of-state which includes the Peng-Robinson (Reference 11) equation and various versions of the Redlich-Kwong (Reference 12) equation. Both oil and gas are treated as mixtures containing an arbitrary number of hydrocarbon and nonhydrocarbon components. In addition, special techniques are implemented in VIP-COMP to insure stability and efficiency of solution for near-critical oil and gas fluid systems.

5000.4.4 1-25


1.1.2 VIP-ENCORE Overview

VIP-ENCORE is a three-phase reservoir simulator which models the immiscible flow of oil, gas, and water within the reservoir. VIP-ENCORE is a special case of the generalized VIP-COMP simulator. Fluid properties can be described according to the “black-oil convention” -- oil at reservoir conditions is a mixture of stock tank oil and dissolved gas. The amount of gas dissolved in the oil is determined by a bubble-point pressure relationship. VIP-ENCORE is able to treat water-oil or gas-water two-phase problems as special cases of the more generalized three-phase fluid system. In addition, VIP-ENCORE can process multicomponent systems whose PVT properties are adequately described by pressure-dependent K-values. Thus, it can be used to model gas condensates and volatile oils more rigorously than conventional black-oil simulators.

1.1.3 VIP-DUAL Overview

NOTE: VIP-DUAL is available as a separately licensed option.

The VIP-DUAL option simulates the performance of reservoirs which are naturally fractured, heterogeneous, or highly stratified. The full dual-porosity, dual-permeability formulation allows flow in both fractures and rock matrix, thereby enabling correct and accurate modeling of reservoirs which may be highly fractured in some regions while unfractured in others. VIP-DUAL must be used in conjunction with either VIP-ENCORE or VIP-COMP. Within VIP-DUAL, the exchange of fluids between the fracture and matrix rock is based on the Warren & Root theory, and the more recent work of Thomas, Dixon, and Pierson. Mass transfer between matrix rock and fractures includes diffusion, convection, imbibition, and gravity drainage. Imbibition and gravity drainage effects are modelled with pseudo-capillary pressure functions that include hysteresis. These functions are automatically and independently determined for the matrix and fractures and account for the matrix block and gridblock sizes. Also available is a dual-porosity/single-permeability option which assumes that the fractures alone are a continuous media and the matrix rock exists only as a source or sink for reservoir fluids.

1-26 5000.4.4


1.1.4 VIP-POLYMER Overview

NOTE: VIP-POLYMER is available as a separately licensed option.

The VIP-POLYMER option simulates the performance of polymer flooded reservoirs. The model takes into account the major physical properties attributed to the flow of polymer solutions through porous media. These include a non-Newtonian viscosity. The polymer is represented by a separate component, present only in the aqueous phase and occupying no volume. VIP-POLYMER must be used in conjunction with either VIP-ENCORE or VIP-COMP.

1.1.5 VIP-THERM Option

VIP-THERM is an extension of the fully implicit formulation of VIP-COMP to include an energy balance, an equilibrium constraint for the water component, heat loss models, and temperature-dependency of all important properties. Two phase behavior models are available: 1) the n-component compositional equation of state model which VIP-THERM shares with VIP-COMP or 2) the dead oil model in which oil is treated as a single non-volatile component.

The VIP-THERM compositional model is a fully implicit, n-component, equation-of-state, thermal simulator. The number of volatile components may be specified as less than or equal to the total number of components. Water and steam properties including density, enthalpy, and viscosity are obtained from a tabular input file which is separate from the file containing the data described in this manual.

The VIP-THERM dead oil model is a fully implict three-phase reservoir simulator which models the flow of oil, water, and steam within the reservoir. This version is a special case of the generalized compositional version. Oil is represented as a single non-volatile component. Oil properties are either calculated by interpolation from input tables or are calculated from input values of oil compressibility, oil coefficient of thermal expansion, oil heat capacity, and oil viscosity as a function of temperature. Water and steam properties including density, enthalpy, and viscosity are obtained from a tabular input file which is separate from the file containing the data described in this manual.

VIP-COMP or VIP-ENCORE initialization data may easily be converted to VIP-THERM format:

1. Specify THERMAL card in VIP-CORE utility data (VIP-CORE Section 2.2.19.1).

2. Specify NCV in the grid system data (VIP-CORE Sections 2.2.3.1 or 2.2.3.2).

3. Replace Physical Property Constants table with VIP-THERM format (VIP-CORE Section 2.2.4.2).

5000.4.4 1-27


4. Replace VIP-ENCORE PVT data with either EOS data (VIP -CORE Section 4.4) or Dead Oil PVT data (VIP-CORE Section 4.7). If PCHOR was specified in VIP-COMP EOS data, that column must be removed before the data will be accepted by VIP-THERM.

5. Specify heat capacity arrays in VIP-CORE array data (VIP-CORE Sections 5.38 and 5.39).

6. Specify heat loss data in VIP-CORE (VIP-CORE Chapter 12).

VIP-COMP and VIP-ENCORE recurrent data may easily be converted to VIP-THERM format:

1. Specify TINJ and QUAL for all water injectors (Sections 3.4.2.1 and 3.4.2.2). Also specify PINJ ( Section 3.4.2.3) for all wells for which steam quality is specified as zero.

2. Specify TINJ for all gas injectors (VIP-EXECUTIVE Section 3.4.2.1).

3. Modify DT cards (VIP-EXECUTIVE Section 7.1.1), ITNLIM cards (VIP-EXECUTIVE Section 7.1.3), and TOLD cards (VIP-EXECUTIVE 7.1.7) to include values for maximum temperature change.

4. Modify TOLR cards (VIP-EXECUTIVE Section 7.1.8) to include an energy balance tolerance.

1.1.6 Shared Features

VIP-COMP, VIP-ENCORE, VIP-DUAL, VIP-POLYMER, and VIP-THERM share all of the same major features. Wells are controlled by a variety of options which allow both rate and pressure constraints. Wells also can be shut in or recompleted automatically. Rates can be adjusted to meet production and injection targets at any of the target levels. These target levels include gathering center, flow station, area, and field.

Separator conditions are also taken into consideration for all of the simulator modules. In VIP-COMP (or in the VIP-THERM compositional model), a multi-component model, separators are required to determine surface production rates. In VIP-ENCORE, separators allow for the additional flexibility of treating flash separation conditions at the surface versus the differential calculations which take place in the reservoir.

Both VIP-COMP and VIP-ENCORE allow fully implicit or IMPES formulations to be selected for the integration of the flow equations. When the DUAL or the THERMAL option is activated, only the fully implicit formulation is accepted for the additional required stability.

Internal calculations are carried out in customary oil field units, but input and output can be in either customary units or the International System of Units (SI) metric system or in laboratory units. Throughout this Reference Manual, units are first listed as the customary units followed by the SI units in parentheses. The user

1-28 5000.4.4


may choose metric pressure units of kg/cm2 (bar) instead of the default kPa. In this case, whenever the documentation reads kPa, kg/cm2 (bar) will be expected. A table of data types and the possible units is given in Section 1.7.

5000.4.4 1-29


1.2 Typical Data Requirements

1.2.1 Well Data

The following well data are required:

n Well completion and workover or stimulation reports indicating treatments (i.e., acid, frac, etc.) and completion intervals.

n Measured data (i.e., rates, pressure) from any productivity or injectivity tests.

1.2.2 Production Histories

The following production histories are required:

n Summary sheets for each well showing monthly volumes of all fluids produced and the number of days or hours on production in the month.

n Plots of individual well performance (i.e., rate, GOR, WOR) versus time.

1.2.3 Pressure History

The following pressure history is required:

n Pressure survey reports for all pressure measurements detailing all pertinent data (i.e., tool identification, tool calibration, tool range, reference elevations, tool run depth, datum depth, all measured pressures) and the results from any pressure analysis work performed (i.e., Horner buildup, etc.).

n Isobaric maps, if available, showing the distribution of pressure in the reservoir at various times in the reservoir’s history.

n Plots showing all pressure data as a function of time or cumulative production.

1-30 5000.4.4


1.3 Data Deck Layout

Time-dependent, or recurrent, data include all data that can be defined or altered subsequent to initialization. With clearly noted exceptions, any item of time-dependent data can be changed any time during the simulation. In addition to the operating characteristics of wells, these data define simulator controls and the frequency and type of output.

Figure 1-1 displays the layout of the recurrent data. The first possible card in the time-dependent data is the RUN card. It is no longer a required card.

The first required data card is the RESTART card, although other optional utility data may precede it. The data following the RESTART card are divided into “time” groups, each of which is read and processed at a time selected by the user. Each group is introduced by a card which specifies when that group is to be processed. The first group is introduced by the START card (either user-specified or automatically inserted) and is read immediately. Each of the remaining groups is introduced either by a TIME card or by a DATE card that tells when the data group should be read. TIME and DATE cards are used interchangeably and may be mixed in the same run.

All simulations are terminated by a STOP card, which may appear anywhere in the time-dependent portion of the data deck. Whenever a STOP card is encountered, no further data processing occurs. The run stops at the time or date appearing on the preceding TIME or DATE card.

An END card must be the last card in the data stream; it acts as an end-of-file.

5000.4.4 1-31


Figure 1-1: Order of Recurrent Data

VIP-EXECUTIVE time-dependent data input allows the user to describe well data, output control, and simulator control. The well data includes the definition of all well and well management level parameters. VIP-EXECUTIVE offers numerous options to define all of the time-dependent data; however, only a minimum amount of recurrent data is actually needed to run the simulator. Change need be specified by exception only.

The required time-dependent well data is displayed in Table 1-1 and Table 1-2 . Table 1-1 lists the minimum data requirements for a production well, while Table 1-2 displays the same information for an injection well. These tables also show the minimum data requirements to implement pressure constraints at the well level. VIP-EXECUTIVE offers several types and levels of production/injection constraints. These are listed in the Chapter 2 Table of Contents for Section 3.3.

A matrix solver option may be specified. At time = 0 either BLITZ or CBLITZ will be defaulted, depending on the problem type. At time > 0 the solver information will be retrieved from the restart file. We suggest the user also enter data for print controls along with the well data that are appropriate for the particular study.

Table 1-3 and Table 1-4 list the VIP-EXECUTIVE data cards that can be used to control production and injection.

1-32 5000.4.4


Table 1-5 and Table 1-6 list all of the required data cards for any given option for both production and injection. Within the lists commas indicate "and" meaning both are required. The "or" indicates any one of the required cards is necessary, and the user chooses which is appropriate.

5000.4.4 1-33


Table 1-1: Minimum Data Requirements for Production Wells

Rate constraint only:

WELL PROD FPERF QMAX

Bottomhole pressure constraint:

WI

WELL PROD FPERF QMAX PI BHP

RFLOW

Tubinghead pressure constraint:

WI

WELL PROD FPERF QMAX PI THP ITUBE BHPTAB

RFLW

Notes:1. For the tubinghead pressure constraint, more than one well can refer to the same BHPTAB.

2. If no productivity is defined by a WI, PI, or RFLOW card, well productivity will be automatically adjusted to cause the well to flow at the rate specified on the QMAX card; i.e., defaults to rate constraint. This can slow convergence whenever the gridblock pres-sure, adjusted to datum depth, approaches the bottomhole pressure.

1-34 5000.4.4


Table 1-2: Minimum Data Requirements for Injection Wells

Rate constraint only:

WELL INJ FPERF QMAX

Bottomhole pressure constraint only:

WI

WELL INJ FPERF QMAX PI BHP

RFLOW

Tubinghead pressure constraint:

WI

WELL INJ FPERF QMAX PI THP TUBE DIAM

RFLOW ITUBE BHITAB

Gas Injectors only:

YINJ

VIP-THERM only:

TINJ QUAL(water/steaminjectors)

PINJ(if QUAL = 0. or 1.)

Note: If no injectivity is defined by a WI, PI, or RFLOW card or by WIL or KHWI data on the FPERF card, the injectivity will be automatically adjusted to cause the well to flow at the rate specified on the QMAX card; i.e., defaults to rate constraint. This can slow conver-gence whenever the gridblock pressure, adjusted to datum depth, approaches the bottom-hole pressure.

5000.4.4 1-35


Table 1-3: Data Cards Valid For Production

ALQ QLIFTM

AREA QMAX

BEGGS QMIN

BHP QMULT

BHPADD QSTMX (VIP-THERM)

BHPITN RCMPPERF

BHPTAB RCMPOR

DIAM RIGDEF

DPBHMX SEPARATOR

ECOLIM TEST

FLOSTA TESTGL

FPERF THP

FTWMIX THPGTB

GASPLANT TRACK

GASTHP TRGOPT

GATHER TRGORD

GLEFMN TRGQMN

GLGMAX TRGTOL

GLGOP TSFM

GLIMIT TSTPRF

GLRADD TUBE

GLRTAB WDNDG

GLRTBP WELL

GTHPWL WI, PI, RFLOW

IPRTRG WLIMIT

ITNSTP WLTYCH

ITNTHP WNDGDV

ITUBE WRKCF1

LSCALE WRKCF2

MBAWG WRKCOEF

NEWSEP WRKDBG

NOFRICTION WRKDLT

ONTIME WRKFAIL

PFMCRV WRKFRQ

PRDMIN WRKGP1

PRFLIM WRKGP2

PROD WRKLIM

PTARG WRKRTO

QLIFT WRKWLM

QLIFTA XFOFF

XFON

1-36 5000.4.4


Table 1-4: Data Cards Valid For Injection

AREA ONTIME

BEGGS PATNCI

BHITAB PATNPP

BHP PATTN

BHPITN PINJ (VIP-THERM)

DIAM PMPTAB

DPBHMX PRIIR

ECOLIM PRIOP

ETRGOP PROJNM

FLOSTA PROJWL

FPERF QMAX

FTWMIX QMIN

GASFUL QUAL (VIP-THERM)

GASMKP QSTMX (VIP-THERM)

GASSKG RECFAC

GASSLS RINJOP

GATHER SEPARATOR

GINJMOB TEST

GINJOP THP

INJ TINJ (VIP-THERM)

INJA TRACK

INJGR TRGTOL

INJMIN TSFM

INJRGR TUBE

INJREGN WELL

INJRNM WI, PI, RFLOW

INJTAR WINJT

IPRTRG WLTYCH

IPUMP WNDGDV

IRDIST WTRPUMP

IRPCTA WTRTHP

IRSRCW XFOFF

ITARG XFON

ITNSTQ YINJ

ITUBE YINJA

LSCALE YINJMK

MBAWG YINJT

NEWSEP YREINJ

NOFRICTION

5000.4.4 1-37


Table 1-5: Production Data Card Cross-Reference

DATA CARD REQUIRED DATA CARDS

Required

WELL --

FPERF WELL QMAX

PROD WELL

QMAX PROD, FPERF

Optional

ALQ THP

AREA --

BEGGS FPERF (horizontal well data)

BHP WI or PI or RFLOW

BHPADD BHPTAB

BHPITN GTHPWL,THPGTB, TUBE, DIAM

BHPTAB ITUBE, THP

DIAM THP, GTHPWL, THPGTB, TUBE

DPBHMX WI or PI or RFLOW

ECOLIM --

FLOSTA --

GASTHP GTHPWL, THPGTB, TUBE, DIAM

GATHER --

GLEFMN QLIFT, QLIFTA

GLGMAX QLIFT, QLIFTA

GLIMIT --

GLRADD GLRTAB

GLRTAB QLIFT, QLIFTA

GLRTBP QLIFT, QLIFTA, GLRTAB

GTHPWL THP, THPGTB, TUBE, DIAM

IPRTRG PTARG

ITNTHP THP

ITUBE THP, BHPTAB

MBAWG --

LSCALE --

NEWSEP SEPARATOR

NOFRICTION FPERF (horizontal well data)

ONTIME --

PFMCRV QLIFT, QLIFTA

PI BHP or THP

PRDMIN --

1-38 5000.4.4


PRFLIM TSTPRF

PTARG --

QLIFT THP

QLIFTA QLIFT, GLRTAB

QMIN

QSTMX

RFLOW BHP or THP

SEPARATOR --

TEST --

TESTGL QLIFT, QLIFTA

THP ITUBE or TUBE, BHPTAB, WI or PI or RFLOW

THPGTB THP, GTHPWL, TUBE, DIAM

TRGTOL PTARG

TSTPRF PRFLIM

TUBE THP, GTHPWL, THPGTB, DIAM

WI BHP or THP

WLIMIT --

WLTYCH --

XFOFF --

XFON --

Table 1-5: Production Data Card Cross-Reference (Continued)


5000.4.4 1-39


Table 1-6: Injection Data Card Cross-Reference


Required

WELL --

FPERF WELL, QMAX

INJ WELL

QMAX INJ, FPERF

TINJ WELL, INJ (VIP-THERM only)

QUAL WELL, INJ (VIP-THERM water/steam injectors only)

PINJ WELL, INJ (VIP-THERM water/steam injectors with QUAL = 0. or 1. only)

Optional

AREA --

BEGGS FPERF (horizontal well data)

BHITAB ITUBE, THP

BHP WI or PI or RFLOW

BHPITN THP

DIAM THP, TUBE

DPBHMX WI or PI or RFLOW

ECOLIM --

FLOSTA --

GASFUL INJ (reinjection)

GASMKP INJ (reinjection), YINJMK

GASSKG INJ (reinjection)

GASSLS INJ (reinjection)

GATHER --

GINJMOB --

GINJOP INJ (reinjection)

INJMIN --

INJREGN RINJOP (INJREG)

INJRGR RINJOP (INJREG)

INJRNM RINJOP (INJREG)

IPRTRG ITARG

IPUMP THP, PMPTAB

IRDIST RINJOP (INJREG)

IRPCTA RINJOP (INJREG)

IRSRCW RINJOP (INJREG)

ITARG --

ITNSTQ --

ITUBE THP, BHITAB

LSCALE --

MBAWG --

NEWSEP SEPARATOR

1-40 5000.4.4


NOFRICTION FPERF (horizontal well data)

ONTIME --

PI BHP or THP

PMPTAB THP, IPUMP

QMIN ECOLIM

RECFAC INJ (reinjection)

RFLOW BHP or THP

RINJOP INJ (reinjection)

SEPARATOR --

TEST --

THP TUBE, DIAM, WI or PI or RFLOW

TRGTOL ITARG

TUBE THP, DIAM

WI BHP or THP

WLTYCH --

WTRPUMP IPUMP, PMPTAB

WTRTHP THP

XFOFF --

XFON --

YINJ INJ

YINJMK INJ (reinjection), GASMKP

YREINJ INJ (reinjection)

Table 1-6: Injection Data Card Cross-Reference (Continued)


5000.4.4 1-41


1.4 Input Data Template

The printout that follows lists the most frequently used simulator data input options.

C ******************************************************************C TIME DEPENDENT DATA CHAPTER 2C ******************************************************************C

DIM PARAMETERS SECTION 2.2.3CC NOTE:THE DIM CARD IS ONLY USED TO MODIFY THE DEFAULT PROGRAM C DIMENSIONS.C

IMPLICIT SECTION 2.3.1CC NOTE:IF THE IMPLICIT CARD IS NOT ENTERED IN AN ISOTHERMAL RUN

STARTING FROM INITIAL CONDITIONS, THE DEFAULT IS IMPES.C

RESTART (STARTING T.S.) SECTION 2.5.1CC NOTE:THE RESTART CARD IS ALWAYS REQUIRED. THE DEFAULT TIMESTEP C NUMBER IS ZERO.C

TITLE1VIP-EXECUTIVE BATCH DATA INPUT TEMPLATE

TITLE2THIS LIST INCLUDES ONLY THE MOST FREQUENTLY USED OPTIONS

CC NOTE: IF TITLE CARDS ARE NOT ENTERED, THE TITLE CONTAINED ON C THE RESTART RECORD WILL BE RETAINED.C

STARTCC NOTE:THE START CARD INDICATES THE BEGINNING OF THE DATA TOC BE INCLUDED IN THIS RUN. IT MAY BE MOVED DOWN IN THEC DATA DECK AS APPROPRIATE FOR STARTING NEW RESTART RUNS.C

OUTPUT OPTION LIST SECTION 6.2PRINT OPTION LIST I/O FREQ SECTION 6.3

CC NOTE:THE PRECEDING TWO CARDS ARE REQUIRED TO GENERATE ARRAYS, C ITERATION SUMMARIES, WELL AND WELL MANAGEMENT LEVELC SUMMARIES, REGION SUMMARIES, SEPARATOR SUMMARIES, ANDC SIMULATION STATISTICS; IF THEY ARE OMITTED ONLY TIMESTEP C SUMMARIES AND END-OF-JOB SIMULATION STATISTICS WILL BE C PRINTED.C++++++++++++++++++++++++++++++++++++++++++++++++++++++++++++++++C MATRIX SOLUTION OPTIONS SECTION 7.2C+++++++++++++++++++++++++++++++++++++++++++++++++++++++++++++++++

1-42 5000.4.4


C[METHOD] (PARAMETERS) SECTION 7.2

CC NOTE:THE MATRIX SOLUTION METHOD MAY BE DEFAULTED.CC-----------------------------------------------------------------C TIMESTEP CONTROL SECTION 7.1C-----------------------------------------------------------------C

DT DT DTMIN DTMAX (DTMPMX) DPMAX DSMAX DVMAX DZMAXSECTION 7.1.1CCC-----------------------------------------------------------------C WELL DATA CHAPTER 3C-----------------------------------------------------------------C SECTION 3.2.1

WELL N (NAME) I J (IGC) (IBAT)WELL NO. NAME I LOC. J LOC. G.C.NO. BAT.NO.

C REPEAT THE DATA CARD AS NECESSARYC

PROD FLUID (UNIT) WELL LIST SECTION 3.4.1INJ FLUID (UNIT) (LEVEL) WELL LIST SECTION 3.4.2

CC NOTE:PROD AND/OR INJ CARDS ARE REQUIRED FOR EACH WELL IN THEC RESERVOIR MODELC

FPERF SECTION 3.2.2WELLL KHW1 L1 KH1X L2 KH2

FPERF SECTION 3.2.2WELLL KH SWMN SWRO W2 L1 KH1 SWMN1 SWRO1 X L2 KH2 SWMN2SWRO2 X L3 KH3 SWMN3SWRO3

CC NOTE:EACH WELL MUST BE INCLUDED IN A SET OF FPERF DATAC

QMAX WELL LIST SECTION 3.5.1C

BHP WELL LIST SECTION 3.6.4BHP1 BHP2 . . . BHPNWDAT1 WDAT2 . . . WDATN

THP WELL LIST SECTION 3.6.5THP1 THP2 . . . THPN

CC NOTE:A BHP OR THP VALUE MAY BE SPECIFIED FOR EACH WELL.C

WI WELL LIST SECTION 3.6.1WI1 WI2 . . . WIN

PI WELL LIST SECTION 3.6.2GF1 GF2 . . . GFNPI1 PI2 . . . PIN

5000.4.4 1-43


RFLOW WELL LIST SECTION 3.6.3RW1 RW2 . . . RWNRB1 RB2 . . . RBNSKIN1 SKIN2 . . . SKINN

CC NOTE:A WI, PI, OR RFLOW VALUE IS REQUIRED IF THP OR BHP IS C DEFINED.C

TUBE WELL LIST SECTION 3.11.1TL1 TL2 . . . TLNDZW1 DZW2 . . . DZWNWDAT1 WDAT2 . . . WDATN

DIAM WELL LIST SECTION 3.11.2DIAM1 DIAM2 . . . DIAMNEPS1 EPS2 . . . EPSN

CC NOTE:TUBE AND DIAM VALUES ARE REQUIRED ONLY IF THP IS SPECIFIED C FOR AN INJECTOR.C

ITUBE WELL LIST SECTION 3.9.1IBHP1 IBHP2 . . . IBHPNDZW1 DZW2 . . . DZWNWDAT1 WDAT2 . . . WDATN

BHPTAB - BHP TABLE SECTION 3.9.2CC NOTE:ITUBE AND BHPTAB DATA ARE REQUIRED ONLY IF THP IS C SPECIFIED FOR A PRODUCERCC----------------------------------------------------------------C POLYMER PHYSICAL PROPERTY DATA SECTION 9.1.2C-----------------------------------------------------------------

POLYMERC-----------------------------------------------------------------C POLYMER CONCENTRATION TABLE SECTION 9.1.3C-----------------------------------------------------------------

POLYTESALT PERM POR

C THE ABOVE CARD IS FOLLOWED BY 1 DATA CARDCP VP0 CPADSRKPOLYMER VISCOSITY ATPOLYMERPERMEABILITYCONCENTRATIONZERO SHEAR RATEADSORPTIONREDUCTION FACTOR

C THE PREVIOUS 2 CARDS ARE REPLACED BY AT LEAST 2 DATA CARDSCC-----------------------------------------------------------------C POLYMER NON-NEWTONIAN VISCOSITY PARAMETERSSECTION 9.1.5C-----------------------------------------------------------------C

SHEAR NSHGAMMAC GAMHF POWN

C THE ABOVE CARD IS FOLLOWED BY 1 DATA CARDCC-----------------------------------------------------------------C POLYMER INACCESSIBLE PORE VOLUME SECTION 9.1.6

1-44 5000.4.4


C-----------------------------------------------------------------C

EPHIP NEP EPHIPCC-----------------------------------------------------------------C CATION EXCHANGE PARAMETERS SECTION 9.1.7C-----------------------------------------------------------------C

IONEX NEXQV XKC

C THE ABOVE CARD IS FOLLOWED BY 1 DATA CARDCC-----------------------------------------------------------------C EFFECTIVE SALINITY PARAMETERS SECTION 9.1.8C-----------------------------------------------------------------

CSEPBETAP CSE1

C THE ABOVE CARD IS FOLLOWED BY 1 DATA CARDCC-----------------------------------------------------------------C SALINITY UNITS SECTION 9.1.9C-----------------------------------------------------------------C

SUNITS UNITSCC-----------------------------------------------------------------C INITIAL ION CONCENTRATIONS SECTION 9.5.1C-----------------------------------------------------------------C

OVER CLWC OVER OR VOVER CARDS ARE USED TO INITIALIZE THE ANION C CONCENTRATIONSC

OVER CAWC OVER OR VOVER CARDS ARE USED TO INITIALIZE THE CATION C CONCENTRATIONSCC-----------------------------------------------------------------C POLYMER PROPERTIES REGION NUMBER SECTION 9.5.1C-----------------------------------------------------------------C

OVER IPOLYTC OVER OR VOVER CARDS ARE USED TO INITIALIZE THE IPOLYT ARRAYCC-----------------------------------------------------------------C POLYMER INJECTION CONCENTRATION SECTION 9.2.1C-----------------------------------------------------------------C

CPINJ WELL LISTCPW1 CPW2 . . . CPWN

CC-----------------------------------------------------------------C ANION INJECTION CONCENTRATION SECTION 9.2.2C-----------------------------------------------------------------C

5000.4.4 1-45


CLINJ WELL LISTCLW1 CLW2 . . . CLWN

CC-----------------------------------------------------------------C DIVALENT CATION INJECTION CONCENTRATION SECTION 9.2.3C-----------------------------------------------------------------C

CAINJ WELL LISTCAW1 CAW2 . . . CAWN

CC-----------------------------------------------------------------C TIME CARDS SECTION 1.3.6 - 2.1.39C-----------------------------------------------------------------

TIME (DATE)STOPEND

C

1-46 5000.4.4


1.5 Data Format

Nearly all data are input in "free field" format. This means it is not necessary to enter numbers in specific columns. Each item of data, or "word", must be separated by either one or more blank columns or by a comma. Unless explicitly stated, all data need not appear on a single card - the continuation character ‘>’ is used to extend data onto the next card.

If more than one set of the same data type is read for the same well, the last set of data encountered is used. For example, if two sets of FPERF cards are read for Well 3, the second set of FPERF data will be used.

Data appearing on the card or cards following a well list have a one-to-one correspondence with the wells in the list.

The data stream includes both numbers and alpha keywords; the latter are used to identify subsequent numbers or select program options. Generally, each new type of data is introduced by an alpha keyword. Secondary keyword items in [ ] are “required mutually exclusive” while those in ( ) are “optional”. The brackets and parentheses should not be input with the data (unless noted); they simple help describe data input options. In the data descriptions that follow, keywords are shown in upper case letters (they can be input in upper or lower case). The names of the variables that are entered as numbers are shown in lower case letters. For example, one of the data cards indicates the time in days when simulated operating conditions are to be changed. In the data description, this is written as:

TIME time

This indicates that the data card must contain the alpha label TIME followed by a number that indicates the time in days. An example of a valid data card follows:

TIME 365

This information could be anywhere on the card so long as nothing else appears in the columns being scanned and there is at least one blank between TIME and 365.

Numbers can be represented in any of the conventional FORTRAN formats. Note the following valid representations of the number 1000:

1000 1000. 1.E3 1E3 0.1E+4 10000E-01

None of the various forms may contain an imbedded blank, since the simulator interprets them as two words rather than one. There is no distinction between integer and floating point representations of numbers. (All numbers are decoded as if they were floating point, then are stored as either integer or floating point variables, depending on use.)

5000.4.4 1-47


Repeated values can be written in shorthand notation to reduce data preparation effort. For example, consider two equivalent ways of specifying the following data card:

Method 1: 10 12.5 12.5 12.5 15. 15. 16.5

Method 2: 10 3*12.5 2*15 16.5

The single "word" 3*12.5 is decoded as 12.5 12.5 12.5 and 2*15 becomes 15 15. On the other hand, 3* 12.5 could not be decoded properly because of the blank between * and 12.5. In this case, the simulator issues an error message. If an error occurs in the time-dependent data, the run stops before the first timestep is taken.

The number of data values on a line is restricted to 20,000. This applies to decoded repeated values, so that 1500*3 becomes 1,500 data values.

Any word beginning with a number (or a decimal point) must be a valid numeric form, or it causes the run to terminate before the first timestep. Any word beginning with a character other than a number (or a decimal point) is treated as alpha data. A # sign before a number causes the number to be interpreted as an alpha string.

Any word beginning with an exclamation point (!) indicates the beginning of inline comments. All text after the exclamation point is ignored by the simulator.

1.5.1 General Utility Data

1.5.1.1 Comment Lines (C)

C comment

Makes a ’comment’ of the field which follows. The alpha label C must be the first word on the card and must be followed by a blank.

See also the use of the inline comment character !, which is discussed in the introduction to this section.

1.5.1.2 Read Data from an External File (INCLUDE)

INCLUDE file-name

NOTE: A relative pathname for an include file is resolved with respect to the current working directory rather than to the directory where the simulation module dataset resides. 00

Definition: 00

1-48 5000.4.4


file-name The pathname to the file from which data should be read.The file name may be contained in double quotes. The file name may contain blanks; in this case, it must be contained in double quotes.

When the INCLUDE card is encountered in the input file, the named file is opened and it becomes the current input file. A fatal error occurs if the file cannot be opened. Reading from the include file stops when either a physical end-of-file is encountered or an ENDINC card is encountered. Reading then continues from the previous input file. Include files can be nested (i.e. contain other INCLUDE cards). However, the nesting level cannot exceed nine.

1.5.1.3 Stop Reading Data from the Current INCLUDE File (ENDINC)

ENDINC

The ENDINC card indicates the end of data for the current include file. When the ENDINC card is encountered on an INCLUDE file, the file is closed and data continues to be read from the previous input file. If INCLUDE files are nested then the nesting level is decreased by one. The ENDINC card is optional in that a physical end-of-file also indicates end of data. A warning message is given when an ENDINC card is encountered on the primary input file.

Examples: ENDINC

1.5.1.4 Echo Print On (LIST)

LIST

LIST and NOLIST cards control printing of card images of the data read. Until a NOLIST Card is entered, LIST is assumed.

Examples: LIST

1.5.1.5 Echo Print Off (NOLIST)

NOLIST

If NOLIST is read, printing of card images is suppressed until a LIST card is read.

Examples: NOLIST

5000.4.4 1-49


1.5.1.6 Skip Data On (SKIP)

SKIP

A SKIP card indicates that all subsequent data is ignored until a NOSKIP card is encountered; i.e. it is as if all the cards were comment lines. The card images are not printed.

Examples: SKIP...NOSKIP

1.5.1.7 Skip Data Off (NOSKIP)

NOSKIP

A NOSKIP card ends the skip data option.

1.5.1.8 Columns To Be Read (NCOL)

NCOL ncol

Definition: 00

ncol Number of columns to be scanned for data; value must be between 30 and 1000, inclusive. Default is 1000.

Only the columns 1 to ncol will be processed. Items beyond column ncol will be ignored (e.g. comments).

Examples: In order to limit processing to the first 45 columns: NCOL 45

1.5.1.9 Data Line Continuation

Data required to be entered in a single record may be input on multiple lines by entering a “greater than” (>) character at the end of each data line to be continued.

1-50 5000.4.4


1.5.2 Well Lists

Several types of data apply to wells. When well data are defined, the alpha label card identifying the type of data also includes a list of wells for which data are being entered. A typical list of well numbers may appear as a well list of:

1 2 3 7 10 25 15 16 17 18 19

Alternatively, this could be represented as:

1 -3 7 10 25 15 -19

In this example, 1 -3 means wells 1 through 3. It is mandatory that at least one blank appear between 1 and -3. Furthermore, a blank may not appear between - and 3. The well numbers in a well list do not have to appear in sequential order.

Data appearing on the card or cards following a well list have a one-to-one correspondence with the wells in the list. For example,

QMAX 1 -4 12 101250 1000 1725 2*800 950

is interpreted as follows:

Well QMAX

1 12502 10003 17254 80012 80010 950

1.5.3 Alternative Well Lists

Wells can also be referred to by their alphanumeric names. However, the well names need to have been defined by the WELL CARD. A typical list of well names may appear as a well list of:

A1 A2 AAA INJEC1 #12345678

Well names beginning with ., +, -, / or a numeral need to be preceded by the # character so as to interpret the string as an alphanumeric. Only the first eight (8) characters of any character string are used for well names.

A group of wells sharing the same root can be selected by use of an identification of the form "root*". For this reason the character * cannot be used as part of a well name.

5000.4.4 1-51


Data appearing on the card or cards following a well list have a one to one correspondence with the wells or group of wells in the list. For example, suppose wells A1, A2, AAA and INJEC1 are defined. Then:

QMAX A* INJEC11000. 2000.

is interpreted as follows:

Well QMAX

A1 1000.A2 1000.AAA 1000.INJEC1 2000.

1.6 Files Used by VIP-EXECUTIVE

It is possible to write enough information onto disk to allow a subsequent run to pick up where the first one left off. The information saved this way is called a "restart record".

VIP-CORE automatically writes a restart record upon completion of the initialization process. The simulation modules also have the ability to write restart records. These subsequent restart records are written as the user directs by means of WREST and/or WLASTR data cards (see Section 6.7). A subsequent run that continues a previous run is a "restart run".

To begin a simulation at time zero, the restart file generated by VIP-CORE is attached. To simulate from a time greater than zero, a restart file created by a previous simulation run is attached.

Along with the standard restart records, VIP-EXECUTIVE simulation modules can write periodic summary records for subsequent processing by ancillary programs. All of the records written can be generated at user-specified time intervals as directed by means of specific data cards. The currently available menu of these data cards, the summary records they control, and the FORTRAN units on which the information is stored include:

PRINT Printer Output (Chapter 6), FORTRAN Unit 6.

WPLOT Production/Injection Data, summarized by well, well management levels, region, and field (Chapter 6), FORTRAN Unit 11 or the vdb file.

WCPLOT Production/Injection Compositional Data, summarized by well, well management levels, region, and field (Chapter 6), FORTRAN Unit 26 or the vdb file.

1-52 5000.4.4


WMAP Grid Array Maps (Chapter 6), FORTRAN Unit 27 or the vdb file.

WMAPOLD Grid Array SIMOUT Maps (Chapter 6), FORTRAN Unit 9.

WREST/ Restart Records (Chapter 6), FORTRAN Unit 2.WLASTR

WFLUX Boundary flux data (Chapter 6), FORTRAN Unit 16. FORTRAN Unit 61 is used instead if the model is being executed as both a fine grid and a course grid.

WFILE Special well file (Chapter 6), FORTRAN Unit 71.

WTRACK Tracking option output (Chapter 6), FORTRAN Unit 17.

To save any or all of these records for subsequent post-processing, appropriate commands must be added to the job control stream for permanent storage of the appropriate FORTRAN units.

5000.4.4 1-53


Simulator I/O is illustrated schematically in Figure 1-2 below along with the appropriate FORTRAN (FT) Unit numbers.

INPUTDECK:FT05

RESTARTFILE:FT03

VIP-EXECUTIVESIMULATION

MODULE

FINE GRIDBOUNDARYFLUXFT16

SCRATCH FILES:FT01 (Formatted)FT08 (Formatted)FT04 (Unformatted)FT21, FT23

RESTART FILE: FT02

PRINTER FILE: FT06

SIMOUT MAP FILE: FT09

PLOT DATA FILE: FT11

WELL LAYER SUMMARY: FT13

TARGETING MESSAGE FILE: FT14

TIMESTEP INFORMATION FILE: FT15

OUTPUT BOUNDARY FLUX (IF NOT ALSO INPUT): FT16

TRACKING OUTPUT: FT17

RFT REPORT: FT18

COMPOSITIONAL PLOT DATA FILE: FT26

MAP FILE: FT27

BUILDUP PRESSURE DEBUG: FT29

STONE PSEUDOS FILE: FT31

TRACK FILE: FT37

TRACER OUTPUT FILE: FT38

WELL PROD/INJ HISTORY FILE: FT40

FLUX DEBUG: FT55

FACILITY UTILIZATION SUMMARY: FT57

OUTPUT BOUNDARY FLUX (IF ALSO INPUT USED): FT61

EXPERT RUN STATISTICS FILE: FT69

WELL REPORT FILE: FT71

SPREADSHEET SUMMARY FILES: FT72 - FT77

INPUT DATA INCLUDE OPTION: FT91-FT99

TIMESTEP SUMMARY FILE: USER-CONTROLLED

Figure 1-2: Simulation I/O Files

1-54 5000.4.4


1.7 Units Conventions

Three unit conventions are available in VIP-EXECUTIVE. The default unit system is FIELD (also known as customary, or English units). The others are METRIC and LAB, which can be selected by placing a METRIC or LAB card in the UTILITY section of the VIP-CORE input file. The METRIC option also can specify pressure as kPa (default), kg/cm2, or bar units. All references to kPa in the METRIC column of the table below can be replaced by kg/cm2 or bar depending on the pressure option selected.

Data Type Field Metric Lab

Angle degrees degrees degrees

Area acres m2 cm2

Compressibility 1/psi 1/kPa 1/psi

Density (water) gm/cc gm/cc gm/cc

Density (oil) gm/cc ordegree API

gm/cc ordegree API

gm/cc or degree API

Formation volume fac-tor (oil)

rb/STB m3/STM3 cc/stcc

Formation volume fac-tor (gas)

rb/MSCFor Z-factor

m3/SM3

or Z-factorcc/scc or z-factor

Gas gravity relative to air at std. cond.

relative to air at std. cond.

relative to air at std. cond.

Gas-liquid ratio SCF/STB SM3/STM3 scc/stcc

Length feet meters cm

Moles lb-moles lb-moles gm-moles

Permeability md md md

Pressure psia kPa psia

Rates 1/day 1/day 1/day

Saturation fraction fraction fraction

Standard pressure (default)

14.65 psia 101.325 kPa or 1.03353 kg/cm2

14.65 psia

Standard temperature (default)

60° F 15° C 15° C

Solution gas-oil ratio SCF/STB SM3/STM3 scc/stcc

Temperature degrees F degrees C degrees C

5000.4.4 1-55


Time days days hours

Transmissibility rb-cp/day/psi m3-cp/day/kPa cc-cp/day/psi

Viscosity cp cp cp

Volume (surface liquid) STB STM3 stcc

Volume (reservoir) rb m3 cc

Volume (surface gas) MSCF SM3 scc

Water-cut fraction fraction fraction

Thermal conductivity Btu/day/ft/° F W/M/° C Btu/day/ft/° F

Thermal trasmissibility Btu/day/° F W/° C Btu/day/° F

Enthalpy Btu/Lb mole kJ/kg mole Btu/Lb mole

Rock heat capacity Btu/ft3/° F kJ/m3/° C Btu/ft3/° F

Fluid heat capacity Btu/Lb/° F kJ/kg/° C Btu/Lb/° F

Data Type Field Metric Lab

1-56 5000.4.4

Chapter

2

00000Utility Data

2.1 Introduction

The following cards can be used to control the program. Of these, the RESTART and END cards are required. The other cards should be used when appropriate. The only order-dependencies involve the RUN, STORAGE, and DIM cards. The other utility data cards may be in any order, but must precede any recurrent data.

2.2 Control

2.2.1 Start of Time-Dependent Data (RUN)

RUN

The RUN card is an optional card signifying the beginning of the simulation data deck. If entered it should be the first card. It should not be entered along with a STORAGE card.

Example:

RUNDIMNBHPMX NBHPQ NPRFMX NPRFTOTNWMAX

5 5 1 50 5IMPLICITRESTART 0TITLE2L4VIPR.DAT RESULTSSTART

5000.4.4 2-57


2.2.2 Calculate Memory Requirement (STORAGE)

If entered the STORAGE card must be the first card in the deck.

STORAGE CORERST

The STORAGE card allows the user to calculate memory requirements for various combinations of grid size, options, formulation and solver. Model description is read from the initialization restart. Recurrent data which affect memory requirements (such as solver and formulation) are obtained from the data set.

2.2.3 Change Default Dimensions (DIM)

If entered the DIM card(s) must immediately follow the RUN/STORAGE card, or be the first card(s) in the deck.

The DIM card allows the user to change the default dimensions on any run starting from initial conditions (time zero) and to increase the dimensions passed on a restart. Multiple sets of DIM cards may be entered, one after the other, or the continuation character > may be used.

If a dimension is not changed on a restart run, the value used will be the one read from the restart file. The defaults noted below only apply until they are initially overwritten by a DIM card.

DIM param1 param2 . . . paramn (card 1)size1 size2 . . . sizen (card 2)

Definitions:

param Alpha labels of those dimension parameters being defined.

NAMAX Amount of workspace available for matrix solution methods. Default is to use internally calculated value.

NAREAX Maximum number of areas (well management hierarchy) to be defined in this run. Default is 5.

NBATMX Maximum number of separator batteries to be defined in this run. Default is 5.

NBHIMX Maximum number of bottomhole pressure tables for injectors to be defined in this run. Default is 3.

2-58 5000.4.4


NBHIQ Maximum number of rate or tubinghead pressure values in any of the bottomhole pressure tables for injectors to be defined in this run. Default is 5.

NBHIV Maximum number of bottomhole pressure values in any of the bottomhole pressure tables for injectors to be defined in this run. Default is 50.

NBHPMX Maximum number of bottomhole pressure tables for producers to be defined in this run. Default is 3.

NBHPQ Maximum number of rate, ratio, water-cut or tubinghead pressure values in any of the bottomhole pressure tables for producers to be defined in this run. Default is 5.

NBHPV Maximum number of bottomhole pressure values in any of the bottomhole pressure tables for producers to be defined in this run. Default is 300.

NCPLMX Maximum number of gasplant interpolation values to be defined in this run. Default is 5.

NCYCMX Maximum number of cycle entries in any cyclic table (CYCLETABLE or CPERF). Default is 1. If it is desired to vary constraints by cycle, this dimension must be increased to the maximum number of cycle specifications in all input CYCLETABLE and CPERF data.

NCYCTM Maximum cycle table number to be defined in this run. Default is 10.

NFSMAX Maximum number of flow stations to be defined in this run. Default is 5.

NGCMAX Maximum number of gathering centers to be defined in this run. Default is 5.

NGLRMX Maximum number of optimal GLR tables (gas lift) to be defined in this run. Default is 1.

NGLRQ Maximum number of rate or water-cut values in any of the optimal GLR tables (gas lift) to be defined in this run. Default is 5.

NGLRV Maximum number of gas-liquid (or gas-oil) ratio values in any of the optimal GLR tables (gas lift) to be defined in this run. Default is 100.

NIADD Amount of workspace to be added to the internally calculated length of the integer work array for the BLITZ matrix solution method. Default is 0.

5000.4.4 2-59


NIRMX Maximum number of injection regions to be defined in this run. Default is 1.

NPMPMX Maximum number of water pump tubinghead pressure tables to be defined in this run. Default is 0.

NPMPV Maximum number of rate/tubinghead pressure values in any of the water pump tubinghead pressure tables to be defined in this run. Default is 1.

NPRFMS Maximum number of real and pseudo perforated intervals (implicit well option) contained in any well to be defined in this run. (See Section 7.3.1.) Default is 7 * NPRFMX.

NPRFMX Maximum number of perforated intervals contained in any well to be defined in this run. Default is 5.

NPRFSOL Maximum numbr of real and pseuso perforations (implicit well option) for all wells to be defined in this run. (See Section 7.3.1.) Default is 7 * NPRFTOT.

NPRFTOT Maximum number of perforations for all wells to be defined in this run. Default is 25.

NPRIMX Maximum number of priorities in the gas project prioritization option to be defined in this run. Default is 1.

NPROMX Maximum number of projects in the gas project prioritization option to be defined in this run. Default is 1.

NPRSYS Number of pressure systems to be defined in this run. Default is 2. This parameter can be specified on the DIM card for the predictive well management calculations.

NPTNMX Maximum number of patterns for the pattern balancing option to be defined in this run. Default is 0.

NPWMAL Number of artificial lift methods in any pressure system to be defined in this run. Default is 1. Currently this number may not be larger than 1. This parameter can be specified on the DIM card for the predictive well management calculations.

NPWMPA Maximum number of producing areas to be defined in this run. Default is 20. This parameter can be specified on the DIM card for the predictive well management calculations.

2-60 5000.4.4


NPWMPM Maximum number of producing mechanisms to be defined in the run. Default is 20. This parameter can be specified on the DIM card for the predictive well management calculations.

NPWMPS Maximum number of passes in any PWM step to be defined in this run. Default is 10. This parameter can be specified on the DIM card for the predictive well management calculations.

NRCMUN Maximum number of recompletion units per well to be defined in this run. Default is 0.

NRIGMX Maximum number of rigs at any well management level to be defined in this run. Default is 10.

NRIGTOT Maximum number of automatic workover rigs plus drilling rigs to be defined in this run. Default is 0.

NSTGMX Maximum number of stages to be defined for any separator battery in this run. Default is 5.

NTHGMX Maximum number of z-factor/viscosity tables for gas producer tubinghead pressure option to be defined in this run. Default is 1.

NTHPGQ Maximum number of pressure or temperature values in any of the gas producer THP tables to be defined in this run. Default is 5.

NTHPGV Maximum number of z-factor/viscosity values in any of the gas producer THP tables to be defined in this run. Default is 50.

NWIMV Maximum number of entries in any well index multiplier table to be defined in this run. Default is 30.

NWMAX Maximum well number to be defined in this run. Default is 10.

NWRKG1 Maximum number of groupings for group 1 to be defined in this run. Default is 20. This parameter can be specified on the DIM card for the automatic workover calculations.

NWRKG2 Maximum number of groupings for group 2 to be defined in this run. Default is 20. This parameter can be specified on the DIM card for the automatic workover calculations.

NXFCON Maximum number of perforations per crossflow well to be defined in this run. Default is NPRFMX, which is usually much too large. The maximum effective number

5000.4.4 2-61


of perforations per crossflow well for this run is printed in the Simulation Statistics report at the end of the run.

NXFWEL Maximum number of crossflow wells to be defined in this run. Default is 10.

size The value or size of the corresponding parameter.

Examples:

DIM NPRFTOT NWMAX NGCMAX NBHPMX 660 660 9 10RESTART 0

2-62 5000.4.4


2.2.4 Material Balance Option (OPTMBL) (Not available in VIP-THERM)

OPTMBL (STBCHK) (PJACO) (DAMP)

The OPTMBL option is derived from an updating procedure for solution unknowns that satisfies the material balance for hydrocarbons and water during each outer iteration. Also, the convergence of the outer iteration is controlled by the residuals in the saturation constraint equation and the well constraint equation. The convergence tolerances may be specified through the TOLSCN and TOLWCN cards, respectively. The use of this option will reduce the number of outer iterations and hence the CPU time. This option is only applicable to the IMPES formulation. OPTMBL only functions for the run in which it is specified, i.e., it is not passed on restarts and must be reentered.

Definitions:

STBCHK Alpha label indicating that an OPTMBL stability test is only to be performed for single-phase gridblocks either with two-phase neighbors or that contain wells. Otherwise, a stability test will be performed for all single-phase gridblocks. For certain compositional problems, this feature could significantly reduce the CPU time. This keyword can be used only for compositional problems.

PJACO Alpha label indicating that a partial Jacobian update of the fugacity equations will be performed, in conjunction with the OPTMBL option. Jacobian coefficients will not be recalculated for gridblocks that satisfy a preset convergence criteria. For certain compositional problems, this feature could result in up to a 20% reduction in CPU time. This keyword can be used only for compositional problems.

DAMP Alpha label indicating that damping the outer iteration solution is allowed.

5000.4.4 2-63


2.2.5 Volume Balance Option (VOLBAL) (Not available in VIP-THERM)

VOLBAL

The relaxed volume balance (VOLBAL) option is derived from an updating procedure for solution unknowns that conserves material for hydrocarbons and water during each outer iteration. The convergence of the outer iteration is controlled by the residuals in the saturation constraint equation and the well constraint equation. The convergence tolerances may be specified through the TOLSCN and TOLWCN cards, respectively. This option is only applicable to the IMPLICIT formulation.

NOTE: Do not use the VOLBAL option with the POLYMER (Section 9.1) option.

2.3 Formulation Options (VIP-COMP or VIP-ENCORE)

Two formulation options are available: IMPES and IMPLICIT. The formulation may be switched from one to another at the beginning of any restart run by entering any one of the cards. If no formulation card is entered in a run starting from initial conditions, the IMPES form of the finite difference equations will be used. If no formulation card is entered in a restart run, the formulation will be the same as used during the previous run. The format of the restart file is independent of the formulation option.

2.3.1 Implicit form of Finite Difference Equations (IMPLICIT)

IMPLICIT

Definition:

IMPLICIT This run will use the implicit form of the finite difference equations. Pressures, saturations and compositions will be solved for simultaneously. Not required for VIP-THERM.

Example:

DIM NBHPMX NBHPQ NPRFMX NPRFTOT NWMAX 5 5 10 50 5 IMPLICIT RESTART 0 TITLE 2 L4VIPR.DAT RESULTS

2-64 5000.4.4


START OUTPUT P SO SW

2.3.2 Explicit form of Finite Difference Equations (IMPES) (Not available in VIP-THERM)

IMPES

Definition:

IMPES This run will use the IMPES form of the finite difference equations. Only pressure will be implicit.

2.4 Results File Control

2.4.1 Plot File Format and Data Selection (PLOT)

PLOT (FORM) (class1 . . .)

Possible Class Names 00

WELL WLLYR GATHER FLOSTA AREA REGION FIELD SURFACE ALL 00

Definitions: 00

FORM This parameter causes formatted records to be written to the plot file. It is required for files that are going to be processed on another computer by PACKER, the Plot and Map Restructuring program. If the FORM parameter is omitted, binary records are written to the plot file. (Binary records are less expensive to write and to store but do not have the flexibility of being able to be used on all computer systems).

This parameter is ignored if plot data is being written to the vdb file.

WELL Well production and injection data.

WLLYR Well production and injection data detailed by layer perforations.

GATHER Gathering center production and injection data.

FLOSTA Flow station production and injection data.

5000.4.4 2-65


AREA Area production and injection data.

REGION Region production and injection data.

FIELD Field production and injection data.

SURFACE Surface network pressure and rate data at nodes. This parameter is applicable only when plot data is being written to the vdb file.

ALL Data for all classes.

NOTE: 1. The PLOT card is needed if summary records of production/injection data are to be written during the simulation for subsequent post-processing. There are three formats. If none of the plot classes are specified, then all of the plot classes (except WLLYR) are written to the plot file at WPLOT frequency (see Chapter 6 - Output Control). If ALL is specified, all of the plot classes (including WLLYR) are written to the plot file. If one or more plot class names are specified, only those plot classes (including WLLYR) are written to the plot file.

2. Plot data is either written to the vdb file or written to the plot file. The default is to use the vdb file. This may be changed by specifying NOVDB (Section 2.4.4).

3. For additional information, see the PLOT file format description in the OUTPUT CONTROL section.

Examples: 00

C To get all classes:PLOT FORM ALL 00

C To select formatted information for WELL, GATHER and FIELD:PLOT FORM WELL GATHER FIELD 00

2.4.2 Compositional Plot File Format and Data Selection (CPLOT)

CPLOT (FORM) (CNDN)(CCNDN)(class1 ...)

Possible Class Names 00

WELL WLLYR GATHER FLOSTA AREA REGION FIELD ALL 00

Definitions: 00

FORM This parameter causes formatted records to be written to the compositional plot file. It is required for files that are going to be processed on another computer by PACKER,

2-66 5000.4.4


the Plot and Map Restructuring program. If the FORM parameter is omitted, binary records are written to the compositional plot file. (Binary records are less expensive to write and to store but do not have the flexibility of being able to be used on all computer systems).

This parameter is ignored if plot data is being written to the vdb file.

CNDN Condensate production rate and condensate production yield for the specified classes will be written to the compositional plot file.

CCNDN Cumulative condensate production volumes for the specified classes except WLLYR will be written to the compositional plot file.

WELL Well compositional production and injection data.

WLLYR Well compositional production and injection data detailed by layer perforations.

GATHER Gathering center compositional production and injection data.

FLOSTA Flow station compositional production and injection data.

AREA Area compositional production and injection data.

REGION Region compositional production and injection data.

FIELD Field compositional production and injection data.

ALL Data for all classes.

NOTE: The CPLOT card is needed if summary records of compositional production/injection data are to be written during the simulation for subsequent post-processing. There are three formats. If none of the plot classes are specified, then all of the plot classes (except WLLYR) are written to the compositional plot file at WCPLOT frequency (see Chapter 6 - Output Control). If ALL is specified, all of the plot classes (including WLLYR) are written to the compositional plot file. If one or more plot class names are specified, only those plot classes (including WLLYR) are written to the compositional plot file.Condensate production rate and yield are not written to the compositional plot file if CNDN is not specified (default). Cumulative condensate production volume is not written to the compositional plot file if CCNDN is not specified (default). The cumulative condensate production volume is not written to the compositional plot file for WLLYR even when CCNDN is specified.

5000.4.4 2-67


The format for CPLOT file is exactly the same as the format for PLOT file. For additional information, see the PLOT file format description in the OUTPUT CONTROL section.

Examples: 00

C To get all classes:CPLOT FORM CNDN CCNDN ALL 00

C To select formatted information for WELL, GATHER and FIELD:CPLOT FORM CNDN WELL GATHER FIELD 00

2-68 5000.4.4


2.4.3 Map File Format (MAP)

The MAP card may be entered only if a MAP card was specified in the VIP-CORE dataset. The MAP card need only be entered in the Utility Data of the simulation run if the file format is to be changed from that used in the run after which this run is restarting; i.e., either VIP-CORE or a previous simulation run. The MAP card is ignored if map data is being written to the vdb file.

By default, the map records will be written to the same type of file (vdb or map file) as that used in the run after which this run is restarting. If the user wishes to switch from vdb output to a map file, then a NOVDB card (Section 2.4.4) should be entered. There is no way to turn vdb back on once NOVDB has been selected.

The arrays to be written to the vdb file/map file may be specified on the recurrent data cards MAPOUT, MAPX, MAPY, MAPZ, MAPXT, MAPYT, MAPZT, MAPWT. Note that these cards and the MAP card do not apply to the SIMOUT map file.

MAP BINARY

FORM

Definitions:

BINARY This parameter causes binary records to be written to the map file (FORTRAN Unit 27). If neither BINARY nor FORM are entered, the format of the map file will not change.

FORM This parameter causes formatted records to be written to the map file (FORTRAN Unit 27). It is required for files that are going to be disposed to another computer, when binary compatibility cannot be guaranteed. If neither BINARY nor FORM are entered, the format of the map file will not change.

5000.4.4 2-69


2.4.4 Flat File(s) for PLOT/MAP Instead of VDB File (NOVDB)

The NOVDB card is used to specify that plot/cplot and/or map array data are to be written to separate files instead of to the vdb file.

It is permissible for plot/cplot data to be written to the vdb file while map array data is written to a map file (FORTRAN Unit 27), or vice versa (plot to FORTRAN Unit 11, cplot to FORTRAN Unit 26).

NOVDB (PLOT) (MAP)

Definitions:

PLOT This parameter causes the plot/cplot data to be written to FORTRAN files rather than the vdb file.

MAP This parameter causes the map array data to be written to a FORTRAN file rather than the vdb file.

NOTE: If no NOVDB or VDB card is entered, plot/cplot data will be written to the vdb file, while map data will be written to whatever file type was used in VIP-CORE.If a NOVDB card is entered with no additional parameters, the effect is the same as entering both PLOT and MAP.

2.4.5 VDB File for PLOT/MAP Data (VDB)

The VDB card is used to cause plot/cplot and/or map array data to be written to the vdb file. It may also be used to request the simultaneous writing of plot/cplot and/or map array data to the respective FORTRAN files.

It is permissible for plot/cplot data to be written to the vdb file while map array data is written to a map file (FORTRAN Unit 27), or vice versa (plot to FORTRAN Unit 11, cplot to FORTRAN Unit 26).

VDB (PLUS (PLOT) (MAP))

Definitions:

PLUS This parameter causes one or both of PLOT and MAP to be written simultaneously to the vdb file and the respective FORTRAN files.

PLOT This parameter causes the plot/cplot data to be written to both the FORTRAN files and the vdb file.

2-70 5000.4.4


MAP This parameter causes the map array data to be written to both a FORTRAN file and the vdb file.

NOTE: If no NOVDB or VDB card is entered, plot/cplot data will be written to the vdb file, while map data will be written to whatever file type was used in VIP-CORE.If the PLUS parameter is entered, at least one of PLOT or MAP must also be entered.If a VDB card is entered with no additional parameters, both PLOT and MAP will only be written to the vdb file.

2.4.6 Flow Vectors (FLOWVEC) (Not accepted by VIP-THERM, see FLOWS card in VIP-CORE manual)

FLOWVEC

The FLOWVEC card is used to indicate that, during this run or a subsequent restart run, the printing and/or mapping of flow vector arrays will be requested.

5000.4.4 2-71


2.5 Pore Volume Deformation Option (PVDEF)

The PVDEF card is an optional keyword that will automatically do the following:

Cause a flat map file to be written. A vdb file will also be written if the data so specifies. A MAP card must have been entered in VIP-CORE. The flat map file will be binary unless the user specifies FORM on the MAP card.

In addition to any arrays written to the map file using the MAPOUT card, the following arrays will be written: P SG SW SO PV PVMUL .

A set of map data will always be written at the time corresponding to the STOP (or END) card, regardless of any WMAP data.

This option will remain true on subsequent restarts. OFF allows the user to disable it.

PVDEF (OFF)

Definitions:

OFF Alpha label turning off the PVDEF option.

2-72 5000.4.4


2.6 Conductive (Leaky) Fault Solution Options (Not available in VIP-THERM)

2.6.1 Segregated Flow Assumption (SEGREG)

SEGREG

Definitions:

SEGREG Alpha label indicating that the segregated flow assumption in conductive faults is to be used. If the SEGREG card is not entered, the fully-mixed assumption is used.

2.6.2 Fully Coupled Calculation (LKCPLD)

LKCPLD ON

OFF

Definitions:

ON Alpha label indicating that the fully coupled calculation for inflow gridblocks is to be performed.

OFF Alpha label indicating that a portion (related to outflow gridblocks’ rates) of the rate calculation for inflow gridblocks (gridblocks receiving fluids from faults) is to be iteratively lagged.

NOTE: If the LKCPLD card is omitted in a run starting from time=0, the default is to use the fully coupled calculation. If the LKCPLD card is omitted in a restart run, the default is to use whatever was the case on the previous run.The lagged option (LKCPLD OFF) in general could significantly reduce the solver CPU time and hence will be more efficient for simple models. However, it may increase the number of Newton iterations and/or cause convergence problems for more complex models (e.g., fine-grid models).

5000.4.4 2-73


2.7 General

The AUTOCYCLE card is required for any run using automatic cycle control (Section 3.17).

AUTOCYCLE

2.7.1 Restarting Runs (RESTART)

This card is required on every run, including runs that begin from initial conditions.

RESTART

istart

STEPNO istart

DATE date month year

TIME time

LAST

(NOOUT)

Definitions:

istart The timestep number from which this run is to begin. A value of zero indicates a run that will start from initial conditions. Default is 0.

STEPNO Alpha label indicating that the restart record written on a certain timestep should be used.

istrt The timestep number from which this run is to begin. A value of zero indicates a run that will start from initial conditions. No default.

DATE Alpha label indicating that the restart record written on a certain date should be used.

d..m..y.. The day, month, and year from which this run is to begin. No default.

TIME Alpha label indicating that the restart record written at a certain time should be used.

time The time, in days, from which the run is to begin. No default.

2-74 5000.4.4


LAST Alpha label indicating that the last record found on the restart file is to be used to start this run. This record must have been written at a time greater than zero.

NOOUT Alpha label indicating that no output restart file (FORTRAN Unit 2) is to be generated during this run. This is useful for quick runs when it is known that no subsequent runs will be restarted from this one.

Example:

For a restart run starting from timestep number 11, whose corresponding date is March 25, 1989, the following three lines function identically.

RESTART 11RESTART STEPNO 11RESTART DATE 25 3 1989

If the output restart file is not needed, the input is

RESTART 11 NOOUT

2.7.2 Descriptive Run Information (TITLE1, TITLE2, TITLE3)

Title cards are not required. If none are read, then the titles contained on the restart record will be retained. Any or all of the three title cards contained on the restart record can be overwritten by entering new title cards.

TITLE1title1

TITLE2title2

TITLE3title3

Definitions:

TITLEn Alpha label indicating that titlen is to be replaced by the information on the following card.

titlen The information on this card will replace that contained on the restart record for title line n.

2.7.3 Beginning of Data (START)

All data appearing between the last recognized utility data and the START card will be ignored. On subsequent restart runs the START card can be moved down in the data deck to cause previously used data to be ignored.

5000.4.4 2-75


The START card is not required to be input. If it is omitted the simulator will effectively insert a START card at the appropriate position in the input data based on the information on the RESTART card. For a run starting at time = 0, the START card is placed immediately following all recognized utility data. When starting from a time > 0, the placement depends on whether a TIME/DATE card exists with the specified time equal to the restart time. If so the START card is placed after the corresponding TIME/DATE card. If not the START card is placed immediately before the next TIME/DATE card after the restart time.

START

Definition:

START Alpha label indicating the beginning of the data to be included in this run.

2.7.4 Time Specification for Reading Data (TIME)

TIME and DATE cards are used interchangeably to control timestep size and output frequency, and may be mixed in the same run. One TIME or DATE card is required.

TIME PLUS delt

time

Definitions:

PLUS Alpha label indicating that the following value is a time increment.

delt Time increment, days. The following data group will be read at the time equal to the current time plus delt.

time Time in days at which the following data group is read. This must be a positive value. Subsequent time values always must increase.

Example:

TIME PLUS 1.0TIME 360..C RECURRENT DATA FOR THE PERIOD

2-76 5000.4.4


C 360 TO 720 DAYS GOES HERE..TIME 720

2.7.5 Date Specification for Reading Data (DATE)

TIME and DATE cards are used interchangeably to control timestep size and output frequency, and may be mixed in the same run. One TIME or DATE card is required.

The date on this card determines the time at which the following data group is read. The program does account for leap years.

DATE day mo yr

Definitions:

day Day of the month.

mo Month expressed as a number from 1 to 12.

yr Year. If yr is entered as a number smaller than 1000, it is interpreted as 1900 + yr (e.g. 75 becomes 1975, 101 becomes 2001). Any value greater than or equal to 1000 is not adjusted.

2.7.6 Run Termination (STOP)

The STOP card terminates the run at the time defined on the TIME or DATE card preceding it. No further data processing will occur after a STOP card is found. If the STOP card is omitted, the END card is used to terminate the run.

STOP

Example:

C Data here is processedSTOPC Data here is not processedEND

2.7.7 End-of-File Marker (END)

The END card must be the last card in the data stream; it acts as an end-of-file

5000.4.4 2-77


marker. When the END card is read, error checking and data processing begins.

END

2-78 5000.4.4

Chapter

3

00000Well Data

3.1 Introduction

The well data includes all data which describes wells; i.e., the definition of all well and well management level parameters. The minimum required well data is shown in Table 1-1 and Table 1-2 . These tables also exhibit the minimum data requirements for wells subject to pressure constraints at the well level.

3.2 Well Location

VIP-EXECUTIVE model wells may be vertical or deviated. A well is referred to as "vertical" if its perforations all have the same areal coordinates; otherwise it is "deviated". Thus, a vertical VIP-EXECUTIVE model well can incline from true vertical. More than one well may coexist in a given gridblock. Also, a well may have more than one perforation in a given reservoir layer.

Additionally an inclined and horizontal well flow correlation option is available. It is activated through parameters on the FPERF card.

If a pattern element option was selected in VIP-CORE (see Section 2.2.3.4 of the VIP-CORE Reference Manual), then all extensive well input and output data (minimum and maximum rates, KH values, production/injection rates and cumulative, etc.) are defined as full well values. The grid geometry is fixed for each pattern element option and is shown in Figures 2-2 to 2-8 of the VIP-CORE Reference Manual. Conventional injector/producer well locations are summarized in Table 3-1 for all the pattern element types.

Table 3-1: Conventional Well Locations For Pattern Element Options

Pattern TypeGrid

OrientationWell Description Well Location

1/8 5- or 9-spot Parallel InjectorCorner ProducerSide Producer (9-spot)

1, NYNX, 11, 1

1/8 5- or 9-spot Diagonal InejctorCorner ProducerSide Producer (9-spot)

1, NYNX, NY(NX-1)/2, 1

5000.4.4 3-79


3.2.1 Well Name and Location (WELL)

Vertical Well

WELL N (NAME) (GRID) IW JW (IGC) (IBAT) nw (wname) (gridname) iw jw (igc) (ibat) (Repeat data card as necessary for subsequent wells.)

Deviated Well

WELL N (NAME)(GRID) IW JW (IGC) (IBAT)nw (wname)(gridname)X X (igc) (ibat)

orWELL N (NAME)(GRID) (IGC) (IBAT)

nw (wname)(gridname)(igc) (ibat)(Repeat data card as necessary for subsequent wells.)

1/4 5- or 9-spot Parallel InjectorCorner ProducerSide Producer (9-spot)Side Producer (9-spot)

1, NYNX, 11, 1NX, NY

1/4 5- or 9-spot Diagonal InjectorCorner ProducerSide Producer (9-spot)Side Producer (9-spot)

(NX-1)/2, NY(NX-1)/2, 11, (NY-1)/2NX, (NY-1)/2

1/12 7-spot -- InjectorProducer

1, NYNX, 1

1/6 7-spot -- InjectorProducerProducer

(NX-1)/2, 11, NYNX, NY

Table 3-1: Conventional Well Locations For Pattern Element Options

Pattern TypeGrid

OrientationWell Description Well Location

3-80 5000.4.4


Definitions:

N Alpha label indicating that this field will contain a well number. Required as the first data field following WELL.

NAME Alpha label indicating that this field will contain a well name.

GRID Alpha keyword indicating that this field will contain the grid name in which the well is perforated.

IW Alpha label indicating that this field will contain the x direction (r direction) index of the gridblock containing the well.

JW Alpha label indicating that this field will contain the y direction ( direction) index of the gridblock containing the well.

IGC Alpha label indicating that this field will contain the number of the gathering center to which the well is attached.

IBAT Alpha label indicating that this field will contain the number of the separator battery to which the well is assigned.

nw Well number. Any value in the range of one to NWMAX (maximum well number for which the program is dimensioned) may be used. A value of zero causes the program to automatically assign a well number to the well, provided a well name is used to define the well. In this case, the well number assigned will be the minimum value between one and NWMAX that has not already been allocated by the user or chosen by the program.

wname Well name of up to eight (8) characters. The first character in the name must be alphabetic unless the name is immediately preceded by the character #. The well name must be unique. A repeated well name will result in an error message and termination of the run. Default is blanks.

gridname Name of the grid in which this well is perforated. If entered, the iw, jw well location must be relative to this grid.

iw X direction (r direction) index of the gridblock containing the well.

5000.4.4 3-81


jw Y direction ( direction) index of the gridblock containing the well.

igc Number of the gathering center to which the well is attached. Default is 1.

ibat Number of the separator battery to which the well is assigned. Alternatives include the battery number of a separator input in the separator data (Surface Separator Data), a value of -npvt which accesses a default separator, and a value of 0:

ibati = nbat (input battery)= -npvt (default separator)= 0

Default is 0 which will result in Separator 1 being assigned if one has been defined or the default separator for PVT region 1 if one has not been defined.

The deviated well option can be used to model any non-vertical well, including horizontal wells. The data format is identical to the format for the vertical well option. However, to define a deviated well, the iw and jw fields must contain the alphabetic character X, if the IW and JW fields appear on the WELL card. If the IW and JW fields are absent from a WELL card, this implies that the well is deviated.

The areal locations of the deviated well completions are entered by perforation as described in the FPERF card.

NOTE: (for both Vertical and Deviated wells):

1.Data fields on the WELL card may be entered in any order. However, the data following the WELL card must be in the order specified by the heading labels.

2.Once a well has been defined with a WELL card, it cannot be redefined. A second WELL card with the same well number results in an error message and terminates the run.

3.A well must be defined by a WELL card before any references can be made to the well on other data cards.

4.NWMAX, the maximum well number permitted, is a limit established by program dimensions. This value is printed on the first page of the program output and may be reset by using the DIM card (see Section 2.2.3).

5.More than one well may be assigned the same (iw, jw) location.

Examples:

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VERTICAL:

C+++++++++++++++++++++++++++++++++C WELLS 1 -364 SAD WELLSC 253 -266 NGI WELLSC 324 -326 WGI WELLSC PUT WELLS INTO THE APPROPRIATE GC/FSCC+++++++++++++++++++++++++++++++++C

WELL NNAME IW JW IGC1 #01-01 18 26 4

DEVIATED:

WELL N NAMEIW JW IGC IBAT5DEV1 X X 2 3

or

WELL N NAMEIGC IBAT5DEV1 2 3

3.2.2 Describe Well Perforations (FPERF)

The FPERF card is used to describe well perforations. Three basic formats are permitted, with optional data for specific situations. If necessary, one or more continuation cards may be used by placing the character ">" as the last string on a card and then continuing the data on the following card. Except for the well number, the data may appear in any order; however, the order on the cards for the perforations must match the order of the headings.

If the water-oil hysteresis model is being used (VIP-CORE Section 4.3.4), ISAT cannot be specified unless hysteresis for the perforation relative permeabilities is deactivated by entering a NOHYSW card before the FPERF card. By default, perforation relative permeabilities are set equal to the hysteretic gridblock values.

NOHYSW

General Format:

FPERF (NOPWDEP) (NORESET) (card 1)WELL (other headings) (card 2)Perforation data cards (card 3)(Card 3 is repeated as necessary to describe all the perforations for each well being perforated.)

5000.4.4 3-83


The three basic formats for the FPERF cards are:

Format A: (Any relative permeability option; each layer specified)

FPERF (card 1) (K) (H)

WELL L (IW JW) (KH)(Other headings)(card 2)(K H)

(k) (h)

nw l (iw jw) (kh) (Other data) (card 3)(k h)

Format B: (Any permeability option; depth to perforations specified)

FPERF (card 1)WELL(IW JW) DTOP DBOT (K)(Other headings)(card 2)nw (iw jw) dtop dbot (k)(Other data)(card 3)

Format C: (Vertical equilibrium relative permeability; each layer specified)

FPERF (card 1)(K)

WELLL (IW JW)HTOP HBOT(KH) (Other headings)(card 2)(k)

nw l (iw jw) htop hbot (kh) (Other data)(card 3)

In the basic formats shown above, the "other headings" may identify 1) data affecting relative permeability endpoints (SWL, SWMN, SWRO, SWMX, SGL, SGMN, SGRO, SGMX, ISAT, ISATI); 2) weighting factors used to interpolate between rock and vertical equilibrium relative permeability (FVEW, FVEG); 3) perforation status (STAT); 4) perforation unit number (UNIT) and/or recompletion unit number (RCMPUNT); 5) well index values for each perforation or the data to calculate the values (WIL, SKIN, RADB, RADW); 6) additional data required for the reduced entry skin (Sr) calculation, to be used in conjunction with the calculation of the well index for each perforation (RKHKV, DHTOP, HTOT); 7) rate dependent skin factor for non-Darcy gas flow (WDL); and 8) inclined and horizontal well data (LENGTH, PWDEP, DIAM, ROUGH, ANGLV, ANGLA). In VIP-THERM, the “other headings” may also identify 1) specified production well gradients (GRAD); and 2) a well index permeability thickness product (KHWI).

For each column heading that appears on card 2, a single data value must appear in the corresponding position on each card 3. An exception to this rule is data for L, the layer number. A range of values may be entered. Some of the data may only be used for certain types of models or in conjunction with other data; such restrictions are noted below.

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Inclusion of the UNIT heading invokes the perforation UNIT option in which layers are grouped into perforation units before perforation production constraints are applied. The unit number has no effect on injection wells.

A separate grouping algorithm is invoked using the RCMPUNT heading and data. This option involves the automatic opening of a group of perforations when another group violates constraints. This unit number has no effect on injection wells.

NOTE: If neither KH nor K are entered, an effective permeability will be computed using gridblock permeability from VIP-CORE. BUT, IF PERMEABILITIES WERE NOT ENTERED IN VIP-CORE (I.E., PORE VOLUMES AND TRANSMISSIBILITIES WERE INPUT), THE EFFECTIVE PERMEABILITY COMPUTED HERE WILL BE ZERO.

Definitions:

NOPWDEP Alpha label indicating that, for horizontal/inclined wells for which PWDEP data is not entered, the depth to center of well segment will be set to the depth of the gridblock containing the perforation.

NORESET Alpha label indicating that the well and perforation cumulative reservoir production arrays (for each of the wells entered), used in conjunction with the WI multiplier tables (Section 3.19.2), should not be reset to zero with the input of new FPERF data. Default is to zero out these arrays.

WELL Column heading for nw, the well number or well name. The well number or name must be entered for each data card. For multiple completions in a single well the alpha label X can be substituted for the well number or well name on each data card after the first.

GRID Column heading for gridname, the name of the grid in which this well perforation is located. The iw, jw and l, if entered for the perforation, must be relative to this grid.

L Column heading for l, the layer number for a completed interval. Required unless dtop and dbot are used. A single number or a range of values may be entered. The format for the range of values is i1 -i2, where i1 i2, or i1 NZ. The last format results in perforations in all layers between layer i1 and the last layer in the appropriate grid, inclusive.

IW Column heading for iw, the x(r) direction gridblock index of the block containing the perforation for a deviated well.

5000.4.4 3-85


JW Column heading for jw, the y) direction gridblock index of the block containing the perforation for a deviated well.

K Column heading for k, the average permeability times the net-to-gross ratio of the perforated interval, md (md). For an areal model, the default is the product of the gridblock

net-to-gross ratio and KxKy ( or KrK ). For a cross-

section model, the default is the product of the gridblock net-to-gross ratio and the appropriate permeability. Not permitted with kh.

H Column heading for h, the thickness of the perforated interval, ft (m). Default is gridblock gross thickness. Not permitted with kh, dtop, dbot, htop, or hbot.

KH Column heading for kh, the average permeability-thickness of the perforated interval, md-ft (md-m) or a permeability-thickness multiplier. Default is the product of the gridblock’s areal permeability and net thickness.

To input a permeability thickness-multiplier, enter a ‘*’ followed by the value. The permeability-thickness of the perforation will be the default calculation times the multiplier.

UNIT Column heading for unit, the perforation unit number. Values must lie between 1 and nprfmx.

RCMPUNT Column heading for rcmpunt, the recompletion unit number. Values must lie between 1 and nrcmun. Permitted only if the dimension nrcmun is greater than zero.

DTOP Column heading for dtop, the subsea depth to the top of a perforated interval, ft (m). May not be used with l, kh, h, htop, or hbot. Must appear with dbot. Required unless l is used. When used with the VE option with corner point geometry, the layer number l must also be specified. Also for this special case, if dtop is entered as -1.0, it will be reset to the gridblock center top depth.

DBOT Column heading for dbot, the subsea depth to the bottom of a perforated interval, ft (m). May not be used with l, kh, h, htop, or hbot. Must appear with dtop. Required unless l is used. When used with the VE option with corner point geometry, the layer number l must also be specified. Also for this special case, if dbot is entered as -1.0, it will be reset to the gridblock center bottom depth.

3-86 5000.4.4


HTOP Column heading for htop, the distance from the top of the gridblock to the top of the perforation, expressed as a fraction of the gross thickness of the gridblock. Default is 0. Permitted only in Format C when using the vertical equilibrium option. The value of htop can be less than 0 in the VE corner-point option.

HBOT Column heading for hbot, the distance from the top of the gridblock to the bottom of the perforation, expressed as a fraction of the gross thickness of the gridblock. Default is 1. Permitted only in Format C when using the vertical equilibrium option. The value of hbot can be greater than 1 in the VE corner-point option.

DHTOP Column heading for dhtop, the distance between the top of the block where the wellbore penetrated the block, and the top of the perforated interval, ft(m). Default is 0., except when DTOP and DBOT are also specified, in which case dhtop is calculated as dtop * gross thickness. The value of dhtop can be less than 0 in the VE corner-point option.

HTOT Column heading for htot, the maximum sand thickness which could be perforated along the wellbore within the gridblock, ft(m); i.e., not necessarily the true vertical net sand thickness. Default is the gross thickness of the block. For the special case of the VE option with corner point geometry, the default is the deepest corner point base depth minus the shallowest corner point top depth.

SWL Column heading for swl, the connate water saturation to be used in denormalizing water relative permeabilities for this perforation. Default is the gridblock’s value. SWMN and SWRO must also be specified.

SWMN Column heading for swmn, the residual water saturation to be used in denormalizing water relative permeabilities for this perforation. Default is the gridblock’s value. SWRO must also be specified.

SWRO Column heading for swro, the water saturation at residual oil to water, to be used in denormalizing water relative permeabilities for this perforation. Default is the gridblock’s value. SWMN must also be specified.

SWMX Column heading for swmx, the maximum water saturation to be used in denormalizing water relative permeabilities for this perforation. Default is 1. SWMN and SWRO must also be specified.

5000.4.4 3-87


SGL Column heading for sgl, the connate gas saturation to be used in denormalizing gas relative permeabilities for this perforation. Default is the gridblock’s value. SGMN and SGRO must also be specified.

SGMN Column heading for sgmn, the residual gas saturation to be used in denormalizing gas relative permeabilities for this perforation. Default is the gridblock’s value. SGRO must also be specified.

SGRO Column heading for sgro, the gas saturation at residual oil to gas, to be used in denormalizing gas relative permeabilities for this perforation. Default is the gridblock’s value. SGMN must also be specified.

SGMX Column heading for sgmx, the maximum gas saturation to be used in denormalizing gas relative permeabilities for this perforation. Default is 1-swl. SGMN and SGRO must also be specified.

ISAT Column heading for isat, the saturation table to be used in calculating relative permeabilities. Default is the gridblock’s rock type.

ISATI Column heading for isati, the imbibition saturation table to be used in calculating relative permeabilities. Default is the gridblock’s rock type.

ICMT Column heading for icmt, the compaction table to be used in calculating effective pore volume and the perforation permeability thickness. Default is the gridblock’s compaction table. The TAMULT column of multipliers will be used for vertical wells; the TVMULT column of multipliers (set equal to TAMULT if not entered) will be used for horizontal/inclined wells.

IWIM Column heading for iwim, the WI multiplier table to be used in calculating the effective perforation well index. Entering this data causes the table lookups for this well to be by perforation. If not entered, or if a subsequent WIMUWL (Section 3.19.1) value is entered for this well, the table lookup will be for the well as a whole. Perforation data only applies to WI multiplier tables with one of the cumulative reservoir production options.

PATTERN Column heading for iptn, the pattern type to use for the perforation when computing the well average pressure with the OUTPAVG algorithm. If not entered, the pattern type is set on the OUTPAVG card. See the OUTPAVG card (Section 6.19) for the possible pattern types.

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FVEW Column heading for fvew, the weighting factor used to interpolate between rock and vertical equilibrium relative permeabilities in the matrix for water-oil systems. A value of 1.0 is full vertical equilibrium. Default is the gridblock’s value.

FVEG Column heading for fveg, the weighting factor used to interpolate between rock and vertical equilibrium relative permeabilities in the matrix for gas-oil systems. A value of 1.0 is full vertical equilibrium. Default is the gridblock’s value.

STAT Column heading for stat, the perforation status indicator. Value is ON or OFF. Default is ON.

WDL Column heading for wdl, the rate dependent skin factor for non-Darcy gas flow.

WIL Column heading for wil, the well index, by perforation. Dimensionless.

If WIL is not specified as a data item, and if any one or more of the data items SKIN, RADB, RADW, RKHKV, DHTOP, or HTOT is specified, then wil will be calculated as follows:

wil

ln radbradw------------- skin Sr+ +

-----------------------------------------------------------=

where = 2 for rectangular grids and varies with ntheta for radial grids. For rectangular grids, can be changed by the FLOANG card. Sr is zero unless any one or more of the data items RKHKV, DHTOP, or HTOT is specified, in which case Sr will be calculated as follows:

Sr 1.35 htoth

---------- 1– 0.825

ln htot rkhkv 7+ 0.49 0.1+ ln htot rkhkv ln rwc 1.95–– =

where rwc = radw e0.2126(Zm/htot +2.753)

and Zm = dhtop + h(hbot - htop)/2

SKIN Column heading for skin, the skin factor for this perforation. Dimensionless. Default is 0.

RADB Column heading for radb, the equivalent radius of the gridblock containing the well, ft (m). Default is the value

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computed in VIP-CORE based on Peaceman’s recommendation (Reference 2):

radb 0.28

kxky------

1 2y

2 kykx------

1 2x

2+

kxky------

1 4 kykx------

1 4+

--------------------------------------------------------------------=

RADW Column heading for radw, the wellbore radius, ft (m). Default is 0.25.

RKHKV Column heading for rkhkv, the ratio of horizontal to vertical permeability within this productive interval. Default is 1.

The following only apply to inclined and horizontal wells

LENGTH Column heading for length, the length of well segment in a well gridblock, ft (m).

PWDEP Column heading for pwdep, the depth to center of well segment, ft (m). If not specified, the depth will be computed from LENGTH and ANGLV.

DIAM Column heading for diam, the diameter of the well segment, ft (m). RADW may be used instead.

ROUGH Column heading for rough, the absolute roughness of the well segment, ft (m).

ANGLV Column heading for anglv, the angle of the source end of the segment to the downward vertical direction, degrees.

ANGLA Column heading for angla, the angle of the segment with respect to the x axis in the areal plane, degrees. Default is 0.

The following only apply to VIP-THERM:

GRAD Column heading indicating the position of grad on the following data cards.

grad Wellbore gradient for the perforated interval, psi/ft (kPa/m). Ignored for injection wells.

KHWI Column heading indicating the position of khwi on the following data cards.

khwi For producers (see Equation , Section 3.6), khwi = 0.001127 WI KH, rB cp/D psia (rm3 cp/D kPa).

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For water/steam injectors (see Equation 3-1 and 3-5 in Section 3.4.2.4), khwi = 0.001127 WI KH rB/D psia (rm3/D kPa).

Do not use for gas injectors.

NOTE: 1.All unread data is given default values prior to calculating perforation properties.

2.In Format B, the simulator automatically generates as many perforations as required by the dtop and dbot data. In this case, iw and jw are held constant over the perforated thickness.

3.In Format C, if k is read, the htop and hbot data are used to determine thickness and position of the perforation. If kh is read, then htop and hbot determine position only.

4.If h is read in Format A when using vertical equilibrium relative permeabilities, htop and hbot are set so as to center the perforation vertically in the gridblock.

5.All perforations for each well being perforated must be defined on consecutive cards.

6.If an interval is specified more than once, the result is multiple perforations; i.e., the KH will be cumulative. The previously specified interval is not replaced.

7.When compaction tables are entered in VIP-CORE, the KH of each perforation is multiplied by the appropriate compaction multiplier. The lookup table is either the one specified with icmt in FPERF data, or the perforation gridblock table specified in VIP-CORE. The TAMULT column of multipliers will be used for vertical wells; the TVMULT column of multipliers (set equal to TAMULT if not entered) will be used for horizontal/inclined wells.

8.Except for one condition, respecifying the FPERF data for a well replaces the entire set of perforations with the new data. The exception is when the new data immediately follows the old data on the same FPERF card. In this case the new data is assumed to be a continuation of the old data.

9.When rate dependent skin factor for each perforation (WDL) is specified, the well index cannot be zero. Well index set to zero is a special case which means adjusting the well index to honor both the rate and bottomhole pressure constraints. In such case, rate dependent skin factor does not have effective meanings. An error message will print in the output and the simulation run will be terminated.

10.The inclined and horizontal well flow correlation option is activated by the presence of the LENGTH, PWDEP, DIAM, ROUGH, ANGLV, and ANGLA keywords on the FPERF card. These data cause the well index and permeability thickness to be computed automatically. Optional keywords to alter the flow correlation and friction factors are

5000.4.4 3-91


given in Section 3.2.6 and Section 3.2.7. If the data for a multilateral well is being input, set the values of ROUGH, the absolute roughness, to -1. This disables the friction loss computation which is currently inaccurate for this type of well. Wellbore gradients will be calculated by the simulator using the volume balance method (Section 3.7.2) which cannot be overridden.

11.If KHWI is input, then a productivity index (specified by WIL data or by a PI, WI, or RFLOW card, Section 3.6) is not required and will be ignored if input.

Example 1:

FPERFWELL L

1 3X 4X 62 1X 2

Example 2:

FPERFWELL L KH1 2 3000X 3 4200X 4 17002 1 5780X 2 3620

In this example perforated intervals are defined for Wells 1 and 2. Well 1 is perforated in layers 2, 3, and 4 with permeability-thickness values of 3000, 4200, and 1700 md-ft, respectively. Well 2 is perforated in layers 1 and 2 with permeability-thickness values of 5780 and 3620 md-ft, respectively.

Example 3:

FPERFWELL L IW JW KH1 7 1 1 1550X 7 1 2 3100X 7 1 3 1550X 8 1 1 120X 8 1 2 240X 8 1 3 120

In this example perforations are defined for a three-dimensional coning problem. The well is completed in layers 7 and 8 in the first radial annulus (I=1). All of the angular increments are completed (J=1,3).

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Example 4:

FPERFWELL L WIL22 3 .85X 4 1.02X 5 1.24

In this example, Well 22 is perforated in layers 3, 4, and 5, and each of the layers has exhibited a different response to the stimulation treatment.

Example 5:

FPERFWELL L RADB RADW SKIN27 1 450. .25 -1.5X 2 450. .25 2.2

In this example, Well 27 is perforated in layers 1 and 2, and each of the layers has exhibited a different response to the stimulation treatment.

Example 6:

FPERFWELL L H RADB RADW SKIN RKHKV DHTOP HTOT35 1 20 450. .25 -1.5 2.0 10. 30X 2 15 450. .25 2.2 5.0 0 25

In this example, Well 35 is perforated in layers 1 and 2, and each of the layers has exhibited a different response to the stimulation treatment. In addition, layer 1 is perforated in the lower 20 feet of layer 1, ten feet below the top of the layer, and layer 2 is perforated in the top 15 feet. Layer 1 is fairly clean, with a kh to kv ratio of 2. Layer 2 has more shaly streaks, with a kh to kv ratio of 5. The wil values will be calculated for each layer, after first calculating a reduced entry skin factor for each layer. The permeability-thickness values stored for each layer will be the layer permeability times htot, since the reduced entry skin factor will compensate for the partial penetration.

Example 7:

FPERFWELL L DTOP DBOT SKIN RKHKV HTOT42 3 7528 -1 .4 4.5 45X 4 -1 7588 -.8 2.5 52

This combination of both L and DTOP/DBOT can only be used with the special case of using the VE option with corner point geometry. In this example, the reduced entry skin factor will be calculated for each layer based on its perforated interval relative to the geometry of the gridblock. The wil values for each layer will then be calculated, and the permeability-thickness stored for the layers will be the layer permeability times its htot.

The following example illustrates the definition of an inclined well, perforated in layers 1-4 and with a horizontal section in layer 4.

5000.4.4 3-93


Example 8:

FPERFWELL L IW JW LENGTH PWDEP DIAM ROUGH ANGLV ANGLA SKIN

2 1 3 1 118 4450 0.25 0.00001 5 40. 5X 2 3 1 120 4490 0.25 0.00001 7 40. 5X 3 3 1 50 4560 0.25 0.00001 10 40 2X 4 3 1 45 4577 0.15 0.00001 20 40 3X 4 4 1 90 4600 0.15 0.00001 20 40 4X 4 5 1 70 4635 0.15 0.00001 90 40 2X 4 6 1 150 4635 0.15 0.00001 90 40 5X 4 7 1 100 4635 0.15 0.00001 90 40 6X 4 8 1 100 4635 0.15 0.00001 90 40 10

The following example illustrates the simulation of a multilateral well.

Example 9:

FPERFWELL IW JW L LENGTH DIAM ROUGH ANGLV ANGLA1 11 11 5 50 0.375 -1.0 90. 0.X 12 11 5 100 0.375 -1.0 90. 0.X 13 11 5 100 0.375 -1.0 90. 0.X 14 11 5 100 0.375 -1.0 90. 0.X 15 11 5 100 0.375 -1.0 90. 0.X 16 11 5 100 0.375 -1.0 90. 0.X 17 11 5 100 0.375 -1.0 90. 0.CX 11 11 5 70.7 0.375 -1.0 90. 45.X 12 12 5 141.4 0.375 -1.0 90. 45.X 13 13 5 141.4 0.375 -1.0 90. 45.X 14 14 5 141.4 0.375 -1.0 90. 45.X 15 15 5 141.4 0.375 -1.0 90. 45.X 16 16 5 13.7 0.375 -1.0 90. 45.CX 11 11 5 50 0.375 -1.0 90. 90.X 11 12 5 100 0.375 -1.0 90. 90.X 11 13 5 100 0.375 -1.0 90. 90.X 11 14 5 100 0.375 -1.0 90. 90.X 11 15 5 100 0.375 -1.0 90. 90.X 11 16 5 100 0.375 -1.0 90. 90.X 11 17 5 100 0.375 -1.0 90. 90.

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The following example illustrates the use of the range of layers option.

Example 10:

FPERFWELL L1 1 -62 4 -53 2X 3X 54 1 NZ5 3 NZ6 2

The following example illustrates the use of the permeability-thickness multiplier.

Example 11:

FPERFWELL L KH1 2 *2.X 3 1000.X 4 *0.5

3.2.3 Describe Well Perforations, VIP-DUAL (FPERF)

The DUAL option allows additional data on the FPERF card. The three basic formats still apply. In the basic formats, the additional "other headings" which apply to DUAL may identify data affecting relative permeability endpoints (SWLF, SWMNF, SWROF, SWMXF, SGLF, SGMNF, SGROF, SGMXF, ISATF, ISATIF), weighting factors used to interpolate between rock and vertical equilibrium relative permeability (FVEWF, FVEGF), a fraction used to allocate the total permeability or permeability-thickness between the matrix and fracture (FM), and a rate dependent skin factor for non-Darcy gas flow (WDLF). Each perforation defined by the user will generate two perforations, one for the matrix and one for the fracture, depending on the value of FM. (see note)

These data can be used in conjunction with any of the other FPERF data. Any restrictions are noted within the definitions.

Definitions:

SWLF Column heading for swlf, the connate water saturation to be used in denormalizing fracture water relative permeabilities for this perforation. Default is the gridblock’s value. SWMNF and SWROF must also be specified.

SWMNF Column heading for swmnf, the residual water saturation to be used in denormalizing fracture water relative permeabilities for this perforation. Default is the gridblock’s value. SWROF must also be specified.

5000.4.4 3-95


SWROF Column heading for swrof, the water saturation at residual oil to water, to be used in denormalizing fracture water relative permeabilities for this perforation. Default is the gridblock’s value. SWMNF must also be specified.

SWMXF Column heading for swmxf, the maximum water saturation to be used in denormalizing fracture water relative permeabilities for this perforation. Default is 1. SWMNF and SWROF must also be specified.

SGLF Column heading for sglf, the connate gas saturation to be used in denormalizing fracture gas relative permeabilities for this perforation. Default is the gridblock’s value. SGMNF and SGROF must also be specified.

SGMNF Column heading for sgmnf, the residual gas saturation to be used in denormalizing fracture gas relative permeabilities for this perforation. Default is the gridblock’s value. SGROF must also be specified.

SGROF Column heading for sgrof, the gas saturation at residual oil to gas, to be used in denormalizing fracture gas relative permeabilities for this perforation. Default is the gridblock’s value. SGMNF must also be specified.

SGMXF Column heading for sgmxf, the maximum gas saturation to be used in denormalizing gas relative permeabilities for this perforation. Default is 1-swlf. SGMNF and SGROF must also be specified.

ISATF Column heading for isatf, the saturation table to be used in calculating fracture relative permeabilities. Default is the gridblock’s rock type.

ISATIF Column heading for isatif, the imbibition saturation table to be used in calculating fracture relative permeabilities. Default is the gridblock’s rock type.

ICMTF Column heading for icmtf, the compaction table to be used in calculating fracture effective pore volume. Default is the gridblock’s compaction table. The TAMULT column of multipliers will be used for vertical wells; the TVMULT column of multipliers (set equal to TAMULT if not entered) will be used for horizontal/inclined wells.

IWIMF Column heading for iwimf, the WI multiplier table to be used in calculating the fracture effective perforation well index. Entering this data causes the table lookups for this well to be by perforation. If not entered, or if a subsequent WIMUWL (Section 3.19.1) value is entered

3-96 5000.4.4


for this well, the table lookup will be for the well as a whole. Perforation data only applies to WI multiplier tables with one of the cumulative reservoir production options.

FVEWF Column heading for fvewf, the weighting factor used to interpolate between rock and vertical equilibrium relative permeabilities in the fracture network for water-oil systems. A value of 1.0 is full vertical equilibrium. Default is the gridblock’s value.

FVEGF Column heading for fvegf, the weighting factor used to interpolate between rock and vertical equilibrium relative permeabilities in the fracture network for gas-oil systems. A value of 1.0 is full vertical equilibrium. Default is the gridblock’s value.

FM Column heading for fm, the fraction of the total k or kh contributed by the matrix. This data is entered only in conjunction with the dual-porosity option. Default value is calculated as the ratio KA/(KA+KAF), where KA is the areal matrix permeability and KAF is the areal fracture permeability for the block being perforated.

WDLF Column heading for wdlf, the rate dependent skin factor for non-Darcy gas flow in the fracture network.

NOTE: Single permeability option will remove perforations from the matrix, and only perforate the fractures.

Example 1:

FPERFWELL L H K FM17 4 12 1750 .02X 5 7 1200 0

In this example the perforated intervals are defined for Well 17. It is completed in layers 4 and 5 of a fractured reservoir (FM option is used). The lengths of the perforated intervals are 12 and 7 feet, respectively, and the average permeabilities of the intervals are 1750 and 1200 md, respectively. In Layer 4, 98% of the production comes from the fracture system and 2% comes from the matrix. In Layer 5, all of the production comes from the fracture system. (Only three perforations would be generated from this data.)

3.2.4 Set Status of Well Perforations (PRFSTAT)

The PRFSTAT card is used to set the status of (previously defined) perforations of wells. The user may define subsets of perforations or all the perforations in a well.

5000.4.4 3-97


PRFSTATWELL STAT (L IW JW GRID UNIT)Perforation data cards

Definitions:

WELL Column heading for nw, the well number or well name. The well number or name must be entered for each data card and must be the first parameter. For multiple completions in a single well, the alpha label X can be substituted for the well number or well name on each data card after the first.

STAT Column heading for stat, the perforation status indicator. Value is ON or OFF. This parameter must be entered.

L Column heading for l, the layer number to which this status change is restricted. A single number or range of values may be entered. The format for the range of values is i1 -i2, where i1i2, or i1 NZ. The last format results in perforations in all layers between layer i1, and the last layer in the appropriate grid, inclusive.

IW Column heading for iw, the x(r) direction gridblock index to which this status change is restricted.

JW Column heading for jw, the y( ) direction gridblock index to which this status change is restricted.

GRID Column heading for the grid name to which this status change is restricted.

UNIT Column heading for unit, the perforation unit number to which this status change is restricted.

NOTE: The WELL parameter must be first. The remaining parameters may be in any order. The parameter STAT is required. For all parameters except WELL and STAT, the character * may be entered to denote that the status change should not be restricted by this parameter. For parameters L, IW, and JW, if a grid name is not entered under the parameter GRID, the data will be presumed to apply to the grid of the first perforation of the well. If a grid name is entered, the data will apply to that grid.

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3.2.5 Well Perforation Tolerances (PERFPT)

PERFPT khmin (rkhmin pvmin rpvmin)

Definitions:

khmin Minimum KH value in well perforations, md-ft (md-m). The perforation status is set to OFF if the KH value in the perforation is less than khmin. Default is 0.

rkhmin Minimum relative KH value in well perforations, fraction. The status of a perforation in a well is set to OFF if the ratio of the KH value in this perforation to the maximum KH value in well active perforations is less than rkhmin. Default is 0.

pvmin Minimum pore volume in gridblocks with well perforations, ft**3 (m**3). The perforation status is set to OFF if the pore volume of the perforation gridblock is less than pvmin. Default is 0.

rpvmin Minimum relative pore volume value in gridblocks with well perforations, fraction. The status of a perforation in a well is set to OFF if the ratio of the gridblock pore volume in this perforation to the maximum gridblock pore volume in well active perforations is less than rpvmin. Default is 0.

Example:

PERFPT 20 0.01 0 0.001

5000.4.4 3-99


3.2.6 Inclined and Horizontal Well Flow Correlation (BEGGS)

The BEGGS card is used to specify the correlation to be used for inclined producers.

BEGGS ON

OFF

surf

Definitions:

ON The Beggs and Brill correlation will be used for inclined producers. Haaland’s correlation will be used for inclined injectors.

OFF Haaland’s single phase equation will be used for producers. This is the default.

surf Liquid surface tension, dynes/cm.

NOTE: If the BEGGS keyword is not input, Haaland’s correlation will be used for all wells.

Example:

BEGGS ON 0.121

3.2.7 Wellbore Friction Pressure Loss (NOFRICTION)

NOFRICTION

Definition:

NOFRICTION Alpha label indicating that the friction kinematic pressure loss will be neglected from the horizontal well pressure loss computation.

NOTE: This option is applicable only to the Horizontal and Inclined well option. When the keyword NOFRICTION is absent, the horizontal and inclined well option computes frictional pressures losses (kinematic and hydrostatic). Note that the hydrostatic pressure loss is always computed.

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3.3 Surface Separation Data

This section does not apply to the VIP-THERM Dead Oil Model.

The surface separation data includes the definition of the set of pressure and temperature conditions through which a produced fluid will be passed. Also defined are the destinations of the product from each stage of the separation process.

3.3.1 Compositional Separator Battery, VIP-COMP or VIP-THERM (SEPARATOR)

Each separator battery may contain an arbitrary number of stages. Each stage contains one feed stream and two output streams: vapor and liquid. Each of the two output streams can itself be split into two streams, each of which may be fed to (1) any downstream separator stage, (2) the gas sales line or (3) the oil sales line.

SEPARATOR ibat(PVTTABLE ipvt)

(1) STAGE TEMP PRES VFRAC VDEST LFRAC LDEST (2) n tn pn vfn1 vdn1 lfn1 ldn1 (3) X X X vfn2 vdn2 lfn2 ldn2 (Type 2 and 3 Data Cards are repeated as necessary to define all the stages of separation.)

Definitions:

ibat List of separator battery numbers.

ipvt EOS table number used for separator calculations (VIP-COMP only). If the particular EOS table has EOSSEP data, the EOSSEP parameters will be used for the calculations. If the PVTTABLE number is not input, EOS table 1 will be assumed.

n Separator stage number. Values range from 1 to the total number of stages.

tn Operating temperature of separator stage n, °F (°C).

pn Operating pressure of separator stage n, psia (kPa).

vfn1 Fraction of the vapor stream leaving separator stage n to be sent to the destination indicated by vdn1. Values must lie in the range 0-1. If vfn1 is less than 1.0, then one type 2 data card must be provided for this stage so that vfn1 and vfn2 sum to 1.0.

5000.4.4 3-101


vdn1 Destination of the first vapor stream leaving stage n. Alternatives include a downstream separator stage, the gas sales line, and vent.

vdn1

m m is a stage number GAS alpha label VENT alpha label

=

lfn1 Fraction of the liquid stream leaving separator stage n to be sent to the destination indicated by ldn1. Values must lie in the range 0-1. If lfn1 is less than 1.0, then one type 2 data card must be provided for this stage so that lfn1 and lfn2 sum to 1.0.

ldn1 Destination of the first liquid stream leaving stage n. Alternatives include a downstream separator stage and the oil sales line.

ldn1m m is a stage number

OIL alpha label

=

X Alpha label that must be entered in the first three locations on the type 2 data card.

vfn2 Fraction of the vapor stream leaving separator stage n to be sent to the destination indicated by vdn2. The values of vfn1 and vfn2 must sum to exactly 1.0.

vdn2 Destination of the second vapor stream leaving stage n. Alternatives include a downstream separator stage and the gas sales line.

lfn2 Fraction of the liquid stream leaving separator stage n to be sent to the destination indicated by ldn2. The values of lfn1 and lfn2 must sum to exactly 1.0.

ldn2 Destination of the second liquid stream leaving stage n. Alternatives include a downstream separator stage and the oil sales line.

NOTE: 1. Stock tank conditions should be entered as the last stage of separation in order to obtain the stock tank liquid volume.

2. The user may optionally enter surface separator equation of state parameters. Because a and b parameters, binary coefficients, and volume shift factors

at reservoir conditions are sometimes not adequate for describing fluid behavior during surface separations, an option to change these parameters is provided. If entered, these data must immediately

3-102 5000.4.4


follow the data for the last stage of the separator battery to which they apply. The user may override the data for any or all stages for a battery.

3. Surface separator equation-of-state parameters cannot be entered without entering all of the separator data, and default values are calculated from reservoir values considering temperature dependency (see Coats, SPE 10512).

4. The default separator is single stage at standard temperature and pressure. A vapor fraction of 1.0 is assigned the destination GAS (gas sales line) and a liquid fraction of 1.0 is assigned the destination OIL (oil sales line).

5. Both the default and the input separators can be accessed for surface volume calculations by means of the REGSEP card.

OMEGAS istgai . . . ancOMEGBS istgbi . . . bnc(DJKSEPcmpj istg

cmpk djk. .. .)

ENDSEP(VSHFTSistgvshftsi ... vshftsnc)

Definitions:

OMEGAS Alpha label indicating that surface separator a values will be entered.

OMEGBS Alpha label indicating that surface separator b values will be entered.

istg Separator stage in the current battery to which the equation-of-state parameters apply.

ai Values of a for each hydrocarbon component.

bi Values of b for each hydrocarbon component.

DJKSEP Alpha label indicating that optional surface separator binary interaction coefficients will be entered.

cmpj Component name of the first component in a binary mixture.

cmpk Component name of the second component in a binary mixture.

5000.4.4 3-103


djk The binary interaction coefficient for mixtures of component j and component k.

VSHFTS Alpha label indicating that optional surface separator volume shift factors will be entered.

vshftsi Surface separator volume shift factor for component i at stage istg.

Example:

C=======================================C COMPOSITIONAL SEPARATOR BATTERYC=======================================

SEPARATOR 1STAGETEMPPRES VFRACVDESTLFRAC LDEST1 100.0665.0 1.GAS 1. 22 132.0100.0 1.GAS 1. 33 126.0 40.0 1.GAS 1. 44 149.0 15.0 1.GAS 1. 55 60.0 14.7 1.GAS 1. OIL

3.3.2 Black-Oil Separator Battery, VIP-ENCORE (SEPARATOR)

The default separator is described in Section 4.7.1 of the VIP-CORE Reference Manual.

Separator data may be entered in VIP-CORE and/or the simulation modules. Separator batteries in addition to those defined in VIP-CORE may be input, and those defined in VIP-CORE may be redefined. This last statement is not true when the PVT interpolation option is in use; separator data may not be input in the simulation modules.

When "black oil" type problems are run in VIP-ENCORE, the PVT data is converted into a multicomponent format, including the use of K-values and z-factors to calculate the phase behavior and volumetric behavior of both oil and gas. This treatment makes it possible for separator conditions to be exactly modeled, while using differential expansion data to describe fluid behavior in the reservoir. This eliminates the conflict between differential and flash volumetrics that creates difficulty for conventional black-oil simulators.

Some of the options for separator data input given in Section 4.7.1 in the reference manual for VIP-CORE are not yet available in the simulation modules. If data for one of these options is available, the option should be used in VIP-CORE.

Separator input data include the following:

1. Definition of the separator configuration. This includes the number of stages, the destinations of the two outflow streams leaving each stage, and the fraction of each outflow stream that flows to each destination.

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2. The density of the oil product (stock tank oil) leaving the last separator stage.

3. The molecular weight of the stock tank oil. Since the separator data should correspond to a fluid described in one of the PVT tables, a liquid molecular weight should not be input. Molecular weight can and will be calculated from the input K-values and the differential liberation data.

4. The equilibrium K-values for each component in the system for each stage of separation. The use of K-values derived from the last step in the differential liberation experiment can lead to large errors in surface volume calculations (for reasons discussed below). This option should only be used when accurate separator K-values and liquid density are known.

One must take great care to insure that the input K-values are consistent with the internally defined component molecular weights, which are printed out in the Default Separator Properties Table in VIP-CORE.

SEPARATOR ibatSTAGE VFRAC VDEST LFRAC LDEST (label card)n vfn1 vdn1 lfn1 ldn1 (type 1 data card)X vfn2 vdn2 lfn2 ldn2 (type 2 data card)(Type 1 and 2 data cards are repeated as necessary todefine all of the stages of separation.)DLIQ MWL (label card)dliq mwl (type 3 data card)KVALUES (label card)COMP STAGE 1 (STAGE 2. . .STAGE n) (label card)comp kval1 (kval2 . . . kvaln) (type 4 data card)(Enter one of these cards for each component in the fluid system.)

Definitions:





vdn1


=

lfn1 Fraction of the liquid stream leaving separator stage n will be sent to the destination indicated by ldn1. Values

5000.4.4 3-105


must lie in the range 0-1. If lfn1 is less than 1.0, then one type 2 data card must be provided for this stage, so that lfn1 and lfn2 sum to 1.0.



OIL alpha label

=

X Alpha label that must be entered in the first location on the type 2 data card.



lfn2 Fraction of the liquid stream leaving separator stage n to be sent to the destination indicated by ldn2. The values of lfn1 and lfn2 must sum to exactly 1.0.


dliq Density of the oil product (stock tank oil) leaving the last separator stage, gm/cc (gm/cc).

mwl Molecular weight of the stock tank oil.

comp Component name (or number).

kvali Equilibrium K-value for this component for stage i.

3-106 5000.4.4


3.3.3 K-Value Separation Data, VIP-ENCORE (SEPARATOR)

SEPARATOR ibatSTAGE VFRAC VDEST LFRAC LDEST (label card)n vfn1 vdn1 lfn1 ldn1 (type 1 data card)X vfn2 vdn2 lfn2 ldn2 (type 2 data card)(Type 1 and 2 data cards are repeated as necessary todefine all of the stages of separation.)DLIQ MWL (label card)dliq mwl (type 3 data card)KVALUES (label card)COMP STAGE 1 (STAGE 2. . .STAGE n) (label card)comp kval1 (kval2 . . . kvaln) (type 4 data card)(Enter one of these cards for each component in the fluid system.)

Definitions:





vdn1


=

lfn1 Fraction of the liquid stream leaving separator stage n to be sent to the destination indicated by ldn1. Values must lie in the range 0-1. If lfn1 is less than 1.0, then one type 2 data card must be provided for this stage so that lfn1 and lfn2 sum to 1.0.



OIL alpha label

=

5000.4.4 3-107


X Alpha label that must be entered in the first location on the type 2 data card.



lfn2 Fraction of the liquid stream leaving separator stage n to be sent to the destination indicated by ldn2. The values of lfnl and lfn2 must sum to exactly 1.0.


dliq Density of the oil product (stock tank oil) leaving the last separator stage, gm/cc (gm/cc).

mwl Molecular weight of the stock tank oil.

comp Component number.

kvali Equilibrium K-value for this component for stage i.

NOTE: Each separator battery may contain any number of stages. Each stage contains one feed stream and two output streams: vapor and liquid. Each of the two output streams can itself be split into two streams, each of which may be fed to; any downstream separator stage, the gas sales line (GAS) or the oil sales line (OIL).Separator data may be entered in VIP-CORE and/or the simulation modules. Separator batteries in addition to those defined in VIP-CORE may be input, and those defined in VIP-CORE may be redefined. This last statement is not true when the PVT interpolation option is in use; separator data may not be input in the simulation modules.The equilibrium K-values for each component in the system for each stage of separation. The use of K-values derived from the last step in the differential liberation experiment can lead to large errors in surface volume calculations (for reasons discussed below). This option should only be used when accurate separator K-values and liquid density are known. When using this option, one must take great care to insure that the input K-values are consistent with the internally defined component molecular weights, which are printed out in the default separator properties table.DEFAULT SEPARATOR

3-108 5000.4.4


The default separator is single stage at standard temperature and pressure. A vapor fraction of 1.0 is assigned the destination GAS (gas sales line) and a liquid fraction of 1.0 is assigned the destination OIL (oil sales line).Both the default and the input separators can be accessed for surface volume calculations by means of the REGSEP Card.Default separator K-values are derived in one of two ways depending on whether or not saturated oil mole fractions at the initial saturation pressure are input in the K-value PVT tabular data. If these mole fractions are not input, default K-values are equal to those in the last entry of the KVTAB table (at standard pressure). This may cause large errors in surface volumes if the default separator is used for separation, since these K-values correspond to the last step in the laboratory differential liberation experiment in which a relatively large fraction of the heavy components is vaporized. If saturated oil mole fractions at the initial saturation pressure are input, this fluid is flashed stepwise through the KVTAB data (corresponding to the differential liberation test) to standard pressure using the input K-values in the table. Default separator K-values are then calculated based on the composition of the total gas liberated between the initial saturation pressure and standard pressure, and the composition of the oil at standard pressure.The default separator oil z-factor is determined by one of several methods which depends on whether or not residual oil z-factor, density, or API gravity is input in the K-value PVT tabular data. If none of these residual oil properties is input, the default separator oil z-factor is given by the oil z-factor in the last entry of the table (at standard pressure) corrected for temperature. Since this neglects oil density variation between reservoir and standard temperature, error in oil surface volume will result. If a residual oil z-factor is input, this is the default separator value. If residual oil density or API gravity is input, in which case oil composition at the initial saturation pressure must also be input, the residual oil composition obtained for the stepwise flash to derive default separator K-values (as described above) is used to calculate a residual oil molecular weight. The default separator oil z-factor is then calculated from this molecular weight and the input residual oil density or API gravity.

Examples:

C=============================================C BLACK-OIL AND K-VALUE SINGLE STAGE

SEPARATORC

=============================================SEPARATOR 1STAGE VFRAC VDEST LFRAC LDEST1 1. GAS 1. OILDLIQ MWL0.8966 200C

5000.4.4 3-109


KVALUESCOMPSTAGE 1

1 89.42 0.0056

3.3.4 Gas Plant Data Input (GASPLANT) (Not available in VIP-THERM)

GASPLANTNKEY ikey ibatKEYCMPvkcmp1 vkcmp2 ... vkcmpj ... vkcmpNI(enter number of KEY component plus composition values forinterpolation. j=1 to number of interpolation points, NI)PLNTRYpr1,1 pr1,2 ... pr1,j ... pr1,NIpr2,1 pr2,2 ... pr2,j ... pr2,NI. . . .. . . .pri,1 pri,2 ... pri,j ... pri,NI. . . prNC,1 prNC,2 ... prNC,j ... prNC,NI(enter the plant liquid molar recovery fractions for each interpolation point, j=1 to number of interpolation values, NI and repeat for all components, i=1 to the number of components, NC)

Definitions:

NKEY Alpha label indicating that the key component plus fraction number and battery are to be read. The cards KEYCMP and PLNTRY defined below should follow the NKEY card, as all values correspond to ibat, the battery defined on this card.

ikey The number of the key component plus fraction to be used in the liquid recovery fraction table look up. The sum of the well stream over all mole fraction from the key component plus all the following components are used in the table look up of component liquid recovery values.

ibat The battery number of the Gas Plant.

KEYCMP Alpha label indicating the key component plus over all mole fractions are to be entered. These are the sum of key component plus mole fractions that are to be used in the liquid recovery fraction table look up. The key component plus fraction is used for ibat, the battery defined on the NKEY card.

3-110 5000.4.4


vkcmp The value of the sum of key component plus fraction to be used as an interpolation value. There are NI number of interpolation point values to be read. They should be on one card and should cover the range of sums that are to be expected in the run. The range of values on this card should be between 0. and 1. NI is determined by the number of values read on the card.

PLNTRY Alpha label indicating that the separate liquid recovery fractions will be entered. The liquid recovery fraction is the molar fraction of the component that will be separated to the liquid stream. The plant recovery values are for ibat, the battery that was defined on the NKEY card.

pr The fraction of the component that will be separated to the liquid stream in the Gas Plant. The liquid recovery fractions are entered for each component as a function of the key component plus mole fraction and one value must be entered for NI points and for each component. The data must be ordered so that the liquid recovery fractions should be entered for component 1 for all values of key component plus fraction interpolation points (NI). The next card is for component 2 recovery fractions at NI points. This continues until all component values have been read. In all there should be (NI * NC) values read. The values must be between 0. and 1.

NOTE: Input to a gas plant is the total well stream, while output is determined by the molar liquid recovery fractions. There are no surface flash calculations as are carried out with a normal surface separator.A gasplant can be entered in VIP-CORE and/or the simulation modules. Surface batteries in addition to those defined in VIP-CORE may be input, and those defined in VIP-CORE can be redefined in the simulation modules.The user may optionally enter the surface separator equation-of-state parameters. These parameters will be used for the stock tank density calculations to obtain the surface rates. The new equation-of-state parameters must follow the last stage of the battery to which they apply. The values of the separator equation-of-state parameters will default to the reservoir values if not given.

Examples:

C=========================================C GAS PLANT SURFACE SEPARATORC =========================================GASPLANT

5000.4.4 3-111


NKEY 6 1KEYCMPC DEFINE KEY COMPONENT PLUS FRACTIONS (NC = 6 TO 8)C NUMBER OF INTERPOLATION POINTS (NI= 11).9999 .108 .104 .098 .075 .065 .047 .028 .018 .010 .000PLNTRYC DEFINE COMPONENT LIQUID RECOVERIES (NI = 11, NC =8).0240 .0240 .0240 .0220 .0170 .0140 .0100 .0050 .0030 .0020 .0020.0070 .0070 .0070 .0060 .0050 .0040 .0030 .0010 .0010 .0000 .0000.0610 .0610 .0590 .0560 .0430 .0370 .0270 .0140 .0090 .0060 .0060.1790 .1790 .1750 .1690 .1370 .1220 .0920 .0550 .0400 .0290 .0290.4680 .4680 .4640 .4530 .4000 .3710 .3050 .2200 .1770 .1480 .1480.9960 .9960 .9960 .9960 .9940 .9930 .9890 .9790 .9690 .9590 .95901.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.0001.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000

3.3.5 Separator Switching (NEWSEP)

The NEWSEP card allows the user to assign separator batteries to a well as a function of either the flowing bottomhole pressure of the well or the tubinghead pressure of the well.

NEWSEP BHPTHP wl

l1 l2 . . . ln h1 h2. . . hn p1 p2. . . pn

Definitions:

BHP Alpha label indicating that the assigning of separator batteries is based on the flowing bottomhole pressure of the well. This is the default.

THP Alpha label indicating that the assigning of separator batteries is based on the tubinghead pressure of the well.

wl List of well numbers for which l, h, and p values are being entered (see Section 1.5.2).

l Separator battery number for low pressure.

h Separator battery number for high pressure.

p Bottomhole/tubinghead pressure, psia (kPa).

NOTE: 1. If flowing bottomhole pressure/tubinghead pressure is less than pi for welli, separator battery li will be used. If flowing bottomhole

3-112 5000.4.4


pressure/tubinghead pressure is greater than or equal to pi, separator battery hi will be used.

2. If it is desired to use one of the default separators defined by VIP-CORE, then l or h should be set to -npvt, where npvt is a PVT table number (VIP-ENCORE) or 1 (VIP-COMP).

3. The THP option on the NEWSEP card may not be used for a well unless a tubinghead pressure constraint (THP card) is specified for that well.

3.3.6 Surface Facility Model Input (TSFM)

separatorbattery

oilstabilizer

gasplant

H/C/well stream

oil rate

gas rate

gas

gas

oil

gas

oilstocktank

Hydrocarbon component recovery factors are specified for the oil stabilizer and gas plant units (moles of component i recovered as oil/mole component i in feed). The component molar rates from the gas plant are converted to surface volumetric rates using specified component molar densities (LB mole/ft3).

The well gas rate is defined at the gas inlet to the gas plant. The default well oil rate is at the oil outlet of the oil stabilizer. However, if the keyword ADDNGL is specified on the TSFM card, the well oil rate is redefined as the sum of the oil from the oil stabilizer plus the natural gas liquids (“oil”) from the gas plant. All well and group constraints apply at these points, unless the keyword DRYTRG is specified on the TSFM card. If so, the gas group constraints apply to the gas leaving the gas plant (after liquids have been stripped).

Gas reinjection options apply to gas produced from the gas plant.

Stream rates, cumulatives, and compositions are reported in the TSFM Surface Facility Model Report. Output is controlled by the PRINT WELLS card.

5000.4.4 3-113


Information on streams leaving the separator battery or on separator stage streams is obtained from the SEPARATOR report.

TSFM (ADDNGL)(DRYTRG)rfs1 rfs2 ... rfsncrfp1 rfp2 ... rfpncdenp1 denp2 ... denpnc

Definitions:

TSFM Alpha label which turns on the Surface Facility Model.

ADDNGL Alpha label which redefines the well oil rate as the sum of the oil from the oil stabilizer plus the natural gas liquids (“oil”) from the gas plant. The default well oil rate is only the oil from the oil stabilizer. This will affect all well group constraints with respect to oil rate.

DRYTRG Alpha label indicating that gas targets apply to gas leaving the gas plant (after liquids have been stripped). The default is for the gas targets to apply to gas entering the gas plant (before liquids have been stripped).

rfsi Hydrocarbon component recovery factors for the oil stabilizer, moles of i produced as oil/mole of i in feed.

rfpi Hydrocarbon component recovery factors for the gas plant, moles of i produced as oil/mole of i in feed.

denpi Hydrocarbon component molar densities used to convert gas plant oil product stream rate to surface volumetric rate, LB moles/ft3.

NOTE: Usage of the TSFM option will change the oil in place calculations for the REGION summary report, based on the possibility that the separators defined do not yield proper stock tank volumes without the inclusion of the oil stabilizer. (i.e., the separators defined are only the high pressure or low pressure separators, and by themselves do not yield correct stock tank volumes.)

3.4 Well Type

Each well must be identified as either a production well or an injection well. The PROD, INJ, and WAG cards are used for this purpose. These cards also allow the user to identify the primary fluid being produced/injected at a rate specified on either the QMAX card or the QMULT card. For producers, other fluids may be produced in conjunction with the primary fluid based upon mobility.

3-114 5000.4.4


If a minimum rate constraint is imposed on a well by means of a QMIN card, the fluid phase used in determining that constraint is defined by the ECOLIM card.

In VIP-EXECUTIVE, the fluid production (injection) of a well may be constrained at five levels: the individual well level, the gathering center level, the flow station level, the area level, and the field level. Multiple constraints may be imposed at each level. For example, at the well level, oil production may be limited by minimum and maximum rates, water cut, GOR, and bottomhole pressure. All of these constraints may be imposed simultaneously. At the gathering center level, production targets can be allocated back to individual wells. At the highest level, field-wide targets can be imposed. The well constraint hierarchy is described in detail in Section 3.4, 3.5, and 3.6.

3.4.1 Production Well Definition (PROD)

A PROD card must precede a QMAX or QMULT card for producers.

A PROD card is required for production wells to define the production phase and units being used for data on the QMAX (maximum well rate) card or the QMULT (multiple rate) card.

PRODW

O

G

STD

RES

MOLES

wl

ALLLIQUIDMULTRT

Definitions:

Alpha label indicating the type of maximum production rate specified on the QMAX card or the QMULT card. Valid labels for fluid production rate are:

W Water.

O Oil.

G Gas.

ALL All fluid components combined.

LIQUID Total liquid (oil plus water).

MULTRT Alpha label indicating the rate defined by the QMULT card is specified separately for each fluid phase. Rates are specified in STB/D (STM3/D) for water and oil, and MSCF/D (SM3/D) for gas. The separate rates are converted internally to reservoir barrel equivalents and summed to obtain a total reservoir barrel rate for all fluid

5000.4.4 3-115


phases combined. This conversion occurs at the start of each timestep. Rates for this type of well must be specified with a QMULT card.

Alpha label indicating units type:

STD Standard conditions. STB/D (STM3/D) for water, oil, or liquid. MSCF/D (SM3/D) for gas. Not permitted for ALL.

RES Reservoir conditions, rb/D (m3/D).

MOLES Lb-moles/D (lb-moles/D). Only permitted for ALL.

wl List of all production wells with rates specified in this manner (see Section 1.5.2).

NOTE: 1. One and only one of the labels W, O, G, ALL, LIQUID or MULTRT must be specified. There is no default. Timestep convergence may be slowed by use of the ALL or MULTRT options.

2. If no units type is specified, the default is STD except for ALL. The default for ALL is RES.

3. When an injection well is converted to a production well, and if the injector’s bhp value is the default value 10,000 psia, then the bhpvalue will be changed to 0 psia. Otherwise, previously input BHP or THP data will be maintained.

4. Specifying a PROD card for a shut-in well will cause the well to be "turned back on".

5. The QMULT card may be used to input rates for the well types, W, O, G, or LIQUID. The appropriate rate(s) are taken from QMULT data, ignoring the remaining rates. For example, for a LIQUID producer the oil and water rates will be summed to get the maximum well rate. The gas rate will not be used.

Example:

CPROD ALL 1 -364 390 -428 438 -507 514 -538C

or

C***************************************************C DEFINE WELL CHARACTERISTICSC***************************************************PROD LIQUID STD 2 -14 18 22 24 -37 41

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3.4.2 Injection Well Definition (INJ)

An INJ card must precede a QMAX card for injectors.

An INJ card is required for injection wells to define the injected phase and units being used for data on the QMAX (maximum well rate) card.

INJ W

STD

RES

FSTD

FRES GATHER

FLOSTA

AREA

FIELD

KEYCMPMI

wlG

Definitions:

Alpha label indicating the maximum injection rate specified on the QMAX card is based on:

W Water (Water and steam in VIP-THERM).

G Gas.


STD Standard conditions, STB/D (STM3/D) for water injectors, MSCF/D (SM3/D) for gas injectors. This is the default.


FSTD A fraction of the total surface production rate of the injected phase (see note below) within a specified level of the well management hierarchy (see below). Note that some options (for example, the UNIFORM gas injection option ) change the definition of FSTD.

FRES A fraction of the total fluid withdrawal (at reservoir conditions) within a specified level of the well management hierarchy (see below). Note that some options (for example, the injection region option) change the definition of FRES.

When FSTD or FRES is specified, the level in the well management hierarchy upon which replacement is based may be specified. The well management level may also be specified for MI injectors with STD or RES specification to identify the level upon which the MI composition determined from the MI plant in the major gas sales option is to be used for the injection composition. In this case, YINJ cards for MI injectors should be omitted and the MI plant

5000.4.4 3-117


calculation for the selected well management level must be invoked (see PLANT card in Section 4.5). The well management levels are:

GATHER Gathering Center. This is the default for FSTD or FRES specification.

FLOSTA Flow station.

AREA Area.

FIELD Field. This is the default for STD or RES specification with MI plant in the major gas sales option.

If a gas conditioning plant in the major gas sales option is present, and keyword DIST is specified in the GASCOND card, a portion of the FSTD gas injectors may be assigned to receive the key component (component icomp in the GASCOND card) removed from the sales gas stream using the following keyword:

KEYCMP Alpha label indicating that the key component stream removed from the sales gas in the gas conditioning plant will be injected into the gas injectors specified in this INJ card. These gas injectors must be specified as FSTD injectors and a GASCOND card with keyword DIST must also be specified.

Alternatively, in the four-component miscible (Todd and Longstaff) option the wells being specified on this card may be identified as MI injectors through input of alpha label MI. In this case, the wells must be specified as FSTD injectors and an MI recovery factor must be specified using a RECFAC card (see Section 4.5.10).

MI Alpha label indicating that the wells being defined are MI injectors in a four-component miscible model. These injectors must be specified as FSTD injectors and an MI recovery factor must be specified using a RECFAC card.

wl List of all injection wells with rates specified in this manner (see Section 1.5.2).

NOTE: 1. Either W or G must be specified. There is no default.

2. Optionally, exactly one of the labels STD, RES, FSTD, and FRES may be specified. If none is specified, STD is the default.

3. Optionally, if either FSTD or FRES is specified, exactly one of the labels GATHER, FLOSTA, AREA, and FIELD may be specified. If none is specified, GATHER is the default.

4. Optionally, if either STD or RES is specified and the major gas sales option (with MI plants) for a well management level is invoked, the well management level (label GATHER, FLOSTA, AREA, or

3-118 5000.4.4


FIELD) may be specified to identify the level upon which the calculated MI composition from the MI plant is to be used as the injection composition. In this case, the injection composition (YINJ card) may be omitted (the input of YINJ card will cause the calculated MI composition to be ignored). If none is specified, FIELD is the default.

5. When a production well is converted to an injection well, any previously input WLIMIT, GLIMIT, or QMIN data will be ignored, and the ECOLIM unit will be set to the injection phase. Also, if the producer’s bhp value is the default value 0 psia, then the bhp value will be changed to 10,000 psia. Otherwise, previously input BHP or THP data will be maintained.

6. Anytime a gas injection well is specified or respecified as either STD or RES, and the wells are not to be identified as MI wells (with MI plant in the major gas sales option), the composition of the injected gas must be defined using the YINJ card.

7. For an FSTD gas injector, the fraction is not of the total gas production but of the gas available for reinjection. This quantity is a function of gas production, gas sales, gas makeup, etc.

8. Optionally, if an FSTD gas well is specified and a GASCOND card with keyword DIST is also present, keyword KEYCMP may be specified.

9. Optionally, if FSTD gas wells are specified and the four-component miscible option is invoked, keyword MI may be specified to identify the MI injectors.

10. Specifying an INJ card for a shut-in well will cause the well to be “turned back on”.

Example:

CINJ G STD 253 -266 324 -326 365 -381YINJ 253 -266 324 -326 365 -381

0.9944 0.0056CINJ G STD GATHER 1 -10

CINJ G FSTD FIELD KEYCMP 11 -20

3.4.2.1 Temperature Specification (VIP-THERM)

A TINJ card must be specified for all injection wells in VIP-THERM.

TINJ wltinj1 tinj2 . . . tinjn

5000.4.4 3-119


Definitions:

wl List of wells for which the data is being specified (see Section 1.5.2).

tinj Injection temperature, °F (°C).

3.4.2.2 Steam Quality Specification (VIP-THERM)

QUAL cards must be specified for water/steam injection wells in VIP-THERM.

QUAL wlqual1 qual2 . . . qualn

Definitions:

wl List of wells for which the data is being defined (see Section 1.5.2).

qual Steam quality, mass fraction vapor.

3.4.2.3 Pressure Specification (VIP-THERM)

If a quality of 0.0 or 1.0 is specified for a water/steam injector, then a PINJ card must be specified for the well.

PINJ wlpinj1 pinj2 ... pinjn

Definitions:

wl List of wells for which the data are being defined (see Section 1.5.2).

pinj Injection pressure, psia (kPa).

3.4.2.4 Treatment of Water/Steam Injectors (VIP-THERM)

The equation describing the mass rate of water/steam injection is:

q 0.001127 WI kh l

l 1=

L

Pbl Pbho Dl Do– –– –=

where

q = H20 injection rate.

3-120 5000.4.4


Pbho = Datum flowing bottomhole pressure.

WI = Well index.

khl = Permeability thickness product for perforation l.

l = Mobility for perforation l.

l = Average density for perforation l.

Pbl = Pressure of gridblock containing perforation l.

= Average fluid density over perforated interval of the well.

Dl = Subsea depth of perforation l.

Do = Datum depth.

The rate of energy injection is given by

E = q H

where H is the enthalpy of the injected steam/water mixture which is assumed constant over the perforated interval and with time. H is calculated from the user specified values of TINJ, QUAL, and PINJ (if QUAL = 0 or 1).

The average density term l is Equation is calculated from phase densities wl, sl and quality Ql:

lwl sl

sl Ql wl gl– +--------------------------------------------=

The perforation quality Ql is calculated from enthalpy H and pressure Pl. If Ql is 0 or 1, then the perforation temperature Tl is calculated. Otherwise, Tl is the water saturation temperature at Pl. Ideally, Pl should be set to Pbh

o Dl Do– – , which is the pressure in the wellbore opposite perforation l. However, this poses problems for a fully implicit model, especially since is a function of l. Hence, we use Pl = Pbl (pressure of griblock containing perforation l. Phase densities wl and sl are evaluated at Pl, Tl.

There are three options for treatment of the mobility term in Equation . Conventionally, is taken as the total mobility of the gridblock containing the perforation:

kroo

-------- krgg

-------- krww

---------+ +=

where the relative permeabilities are evaluated at gridblock conditions using the perforation relative permeability functions and the viscosities are gridblock values. There are two disadvantages to this method in thermal simulation:

5000.4.4 3-121


1. Extreme nonlinearities are introduced into Equation , mainly through temperature dependence of the viscosities. Stable timestep size will be significantly reduced relative to other methods, especially near the initiation of injection (at low temperatures).

2. If the gridblock is large relative to the drainage radius of the well, the mobility should be evaluated at near-wellbore conditions rather than at average gridblock conditions.

The total mobility method is available as an option. In the endpoint method (default), it is assumed that the formation in the vicinity of the wellbore which controls injectivity is quickly reduced to some irreducible oil saturation which depends on Ql. The effect of the saturation changes occurring during this period on mobility are neglected. Perforation mobilities are given by the volumetric average of the water mobility at residual oil to water and the steam mobility at residual oil to gas:

l

1 Ql–

wl

-------------- krwrolwl

-----------------Ql

sl

------ krgrolsl

----------------+

1 Ql–

wl

--------------Ql

sl

------+

-------------------------------------------------------------------=

where relative permeabiliites and phase densities and viscosities are evaluated at Pl, Tl. The third option is that the perforation mobilities may be (in effect) user-specified as constant values using the KHWI option on the FPERF card (Section 3.2.2). For injectors, KHWI is defined as:

KHWIl 0.001127 WI khl l =

The WINJMOB card allows the user to select between the first two options.

WINJMOB ENDPOINT

TOTAL

Definitions:

ENDPOINT Alpha label which activates endpoint mobility, Equation (default).

TOTAL Alpha label which activates total mobilty option, Equation .

Previous to version 1.8R, the endpoint method was used with the following differences:

1. Ql in Equation and was set to the user specified value of QUAL.

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2. Phase densities and viscosities in Equation and were evaluated at the user-specified value of TINJ and the corresponding water saturation pressure.

Simulation results using this method can be reproduced by specification of the keyword OLDINJ.

OLDINJ

5000.4.4 3-123


3.4.3 Define Additional Injection Rate for FSTD or FRES Wells (INJA)

The INJA card is used to specify an additional injection rate for either FRES or FSTD wells.

INJA qa wl

Definitions:

qa Additional injection rate for FSTD or FRES wells.

wl List of injection wells for which qa are being specified (see Section 1.5.2)

NOTE: The unit is determined by the INJ card. If the well specified on the INJ card is an FRES well, then qa is reservoir rate. If it is an FSTD well, then qa is surface rate.The INJA card should be specified after the INJ card.This option can be used for both the standard reinjection or general injection option, but this data is ignored when the guide rate voidage injection option (INJTAR) is used.If the well is a gas injection well using the standard reinjection option, the YINJA card can be used to specify the gas composition for the additional rate.

3.4.4 Computation of Mobility for Gas Injectors (GINJMOB)

The GINJMOB card is used to specify the method to use for computing the mobility for gas injection wells.

GINJMOB ENDPOINT

TOTAL

Definitions:

ENDPOINT Alpha label indicating that endpoint mobilities will be used for gas injectors. This is the default.

TOTAL Alpha label indicating that total gridblock mobilities will be used for gas injectors.

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3.4.5 Computation of Mobility for Water Injectors (WINJMOB)

The WINJMOB card is used to specify the method to use for computing the mobility for water injection wells.

WINJMOB ENDPOINT

TOTAL

Definitions:

ENDPOINT Alpha label indicating that endpoint mobilities will be used for water injectors. This is the default.

TOTAL Alpha label indicating that total gridblock mobilities will be used for water injectors.

3.4.6 Production Rates Outer Iteration Number (ITNSTP)

The ITNSTP card allows the user to specify the outer iteration number after which production rates will not be recomputed for the remainder of the timestep. The maximum drawdown constraint option (DPBHMX card) makes use of this iteration number to fix the bottomhole pressure of a constrained producer for the remainder of the timestep.

ITNSTP itnstp

Definition:

itnstp Outer iteration number after which production rates will not be recomputed for the timestep. Default is 99999, meaning the rates will be computed every outer iteration.

3.4.7 Water Injection Rates Outer Iteration Number (ITNSTQ)

The ITNSTQ card allows the user to specify the outer iteration number after which water injection rates will not be recomputed for the remainder of the timestep. The maximum drawdown constraint option (DPBHMX card) makes use of this iteration number to fix the bottomhole pressure of a constrained injector for the remainder of the timestep.

Some options, such as the injection region option, require water injection rates to be recomputed during each outer iteration that their computations are being made. The actual itnstq value used will be the minimum value needed to satisfy this requirement and the users input.

5000.4.4 3-125


ITNSTQ itnstq

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Definition:

itnstq Outer iteration number after which water injection rates will not be recomputed for the timestep. Default is 99999, meaning the rates will be computed for every outer iteration.

3.4.8 Gas Reinjection Rates Outer Iteration Number (ITNGRE)

The ITNGRE card allows the user to specify the outer iteration number after which gas reinjection rates will not be recomputed for the remainder of the timestep.

ITNGRE itngre

Definition:

itngre Outer iteration number after which gas reinjection rates will not be recomputed for the timestep. Default is -1, meaning an internal algorithm is used to determine the number of iterations.

NOTE: 1. The gas reinjection rates are used for FSTD gas injectors and in the general injection region option (RINJOP INJREG).

2. The default algorithm for computing the value of itngre is

itngre = max(min(itnmax - 3, 3), 1),

where itnmax is the maximum number of outer iterations per timestep from the ITNLIM card.

5000.4.4 3-127


3.4.9 Change Well Type Class (WLTYCH)

The WLTYCH card is used to immediately change the well type of one class of wells to another type.

WLTYCHFROM *TO *

WO (STD)

where * =PROD G (RES)ALL (MOLES)LIQUIDMULTRT

or

(STD)(GATHER)INJ W (RES)(FLOSTA)

G (FSTD)(AREA)(FRES)(FIELD)

Definitions:

Alpha label indicating the type of maximum production rate specified on the QMAX card or the QMULT card. Valid labels for fluid production rate are:

W Water.

O Oil.

G Gas.

ALL All fluid components combined.

LIQUID Total liquid (oil plus water).

MULTRT Rate for each fluid phase. See PROD card for more detailed discussion.


STD Standard conditions. STB/D (STM3/D) for water, oil, or liquid. MSCF/D (SM3/D) for gas. Not permitted for ALL.


MOLES Lb-moles/D (lb-moles/D). Only permitted for ALL.

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Alpha label indicating the maximum injection rate specified on the QMAX card is based on:

W Water.

G Gas.




FSTD A fraction of the total surface production rate of the injected phase within a specified level of the well management hierarchy (see below).

FRES A fraction of the total fluid withdrawal (at reservoir conditions) within a specified level of the well management hierarchy (see below).

When FSTD or FRES is specified, the level in the well management hierarchy upon which replacement is based may be specified. These are:

GATHER Gathering Center. This is the default.


AREA Area.

FIELD Field.

NOTE: 1. At the exact moment in the program that this card is read, all wells of the type designated by the FROM data will be converted to wells of the type designated by the TO data.

2. It is up to the user to make sure all well data are consistent with this switch.

5000.4.4 3-129


3.4.10 Extra Pass to Compute Produced Gas Composition (REINJCOMP)

The REINJCOMP card is used to confirm the correctness of the composition of the produced gas by performing an extra pass through the well calculations. This will not change the composition of any reinjected gas based on produced gas, but will allow the output of the produced gas composition in compositional reports and plotfile to equal the reinjection gas composition. It should have no effect on the simulation results, but it will result in a noticeable increase in CPU time. This is why the default is OFF.

REINJCOMP ON

OFF

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3.5 Well Constraints

Each well produces/injects at the maximum rate defined by a QMAX card or a QMULT card, subject to reduction to honor other applicable constraints.

3.5.1 Maximum Rate (QMAX)

Must be preceded by a PROD or INJ card (Section 3.4.1 and 3.4.2).

The QMAX card defines the maximum rate a well is allowed to produce/inject. A QMAX card, or a QMULT card, is required for the well to flow.

QMAX wl qmax1 qmax2 . . . qmaxn

Definitions:

wl List of wells for which qmax values are being specified (see Section 1.5.2).

qmax Maximum rate at which the well is allowed to produce/inject. Units are determined by the PROD or INJ card. Default is zero.

NOTE: 1. The well produces/injects at a rate of qmax unless this causes a violation of one of the other constraints defined by the user. In this event, the constraint is observed, which causes a rate reduction.

2. The number of qmax values must equal the number of wells in the well list.

3. For the FSTD injection option, qmax is the fraction of the total surface production rate of the injected phase within the appropriate level. For the FRES injection option, qmax is the fraction of the total reservoir volume production rate within the appropriate level. Note that certain options (UNIFORM gas injection, injection region) change the definitions of FSTD and FRES.

Example:

CINJ W STD 382 -389 429 -437 508 -513

QMAX 382 -389 429 -437 508 -5138*10000 9*0 6*10000

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3.5.2 Water Limit - Water Cut, Rate or Liquid-Gas Ratio Constraint (WLIMIT)

This card can be used in conjunction with a TEST card (Section 3.5.13).

The WLIMIT card allows the user to define a maximum water cut, water rate, or liquid-gas ratio for a production well.

PLUGWLIMIT SHUTIN (LGR) wl

LIMITPLUGPLUS

wmax1 wmax2 . . . wmaxn (wcut1 wcut2 . . . wcutn)

Definitions:

PLUG Alpha label indicating that the well is automatically recompleted whenever water cut exceeds wmax. When the well has just one active perforation, the check is against wcut instead of wmax. Recompletion consists of plugging the perforation with the highest water cut. If there is only one perforation, the well is permanently shut in. Once a perforation has been plugged, it never produces/injects again, unless the well is reperforated by an FPERF card.

SHUTIN Alpha label indicating that the well is automatically shut in whenever water cut exceeds wmax. It periodically is tested according to data on the TEST card. If water cut is found to be less than wmax during a test, the well is returned to production.

LIMIT Alpha label indicating that the water production rate is not allowed to exceed wmax, STB/D (STM3/D). The specified production rate is reduced, if necessary. The water production limit is rechecked every timestep.

PLUGPLUS Alpha label indicating that when a well is recompleted with the PLUG option as described above, all perforations in the list after the plugged one will also be plugged.

LGR Alpha label indicating that the PLUG and SHUTIN options apply to liquid-gas ratio instead of water cut. The LIMIT option is unaffected.

wl List of wells to which these restrictions apply (see Section 1.5.2).

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wmax Limiting water cut or water production rate, or liquid-gas ratio, depending on the option selected.

wcut Limiting water cut or liquid-gas ratio for wells with only one active perforation. Available only for the PLUG and PLUGPLUS options. This entire card may be omitted, in which case the default is wcuti = wmaxi.

NOTE: 1. One and only one of the PLUG, SHUTIN, LIMIT, or PLUGPLUS labels must be specified.

2. The number of wmax and wcut values must equal the number of wells in the well list. None of these restrictions is applied to wells not named on a WLIMIT card.

3. Only the SHUTIN option is affected by the TEST card.

4. WLIMIT data may not be specified for injection wells.

5. Liquid-gas ratios are specified in units of STB/MMSCF (STM3/KSM3).

6. Specifying a WLIMIT card for a shut-in well will cause the well to be "turned back on".

Example:

TIME 5CWLIMIT SHUTIN1 -252 267 -323 327 -364 390 -428 252*.99 57*.99

38*.99 39*.99 C

3.5.3 Gas Limit - GOR or Rate Constraint (GLIMIT)


The GLIMIT card allows the user to define a maximum gas-oil ratio or gas rate for a production well.

GOR or Rate Constraint

PLUGGLIMIT SHUTIN wl

LIMITPLUGPLUS

gmax1 gmax2 . . . gmaxn(gorm1 gorm2 . . . gormn)

Definitions:

5000.4.4 3-133


PLUG Alpha label indicating that the well is automatically recompleted whenever the producing gas-oil ratio exceeds gmax, SCF/STB (SM3/STM3). When the well has just one active perforation, the check is against gorm instead of gmax. Recompletion consists of plugging the perforation with the highest gas-oil ratio. If there is only one perforation, the well is permanently shut-in. Once a perforation has been plugged, it never produces/injects again unless the well is reperforated by an FPERF card.

SHUTIN Alpha label indicating that the well is automatically shut in whenever the producing gas-oil ratio exceeds gmax, SCF/STB (SM3/STM3). It is tested periodically according to data on the TEST card. If the gas-oil ratio is found to be less than gmax during a test, the well is returned to production.

LIMIT Alpha label indicating that the gas production rate is not allowed to exceed gmax, MSCF/D (SM3/D). The specified production rate is reduced, if necessary. The gas production limit is rechecked every timestep.

PLUGPLUS Alpha label indicating that when a well is recompleted with the PLUG option as described above, all perforations in the list before the plugged one will also be plugged.


gmax Limiting gas-oil ratio or gas production rate, depending on the option selected.

gorm Limiting gas-oil ratio for wells with only one active perforation. Available only for the PLUG and PLUGPLUS options. This entire card may be omitted, in which case the default is gormi = gmaxi.

NOTE: 1. One and only one of the PLUG, SHUTIN, LIMIT, or PLUGPLUS labels must be specified.

2. The number of gmax and gorm values must equal the number of wells in the well list. None of these restrictions is applied to wells not named on a GLIMIT card.


4. GLIMIT data may not be specified for injection wells.

5. Specifying a GLIMIT card for a shut-in well will cause the well to be "turned back on".

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3.5.4 Steam Limit - Steam Rate or Steam-Oil Ratio Constraint (SLIMIT) (VIP-THERM)


The SLIMIT card allows the user to define a maximum steam rate or steam-oil ratio for a production well.

PLUGSLIMIT SHUTIN (SOR) wl smax1 smax2 . . . smaxn (smaxl1 smaxl2 . . . smaxln)

Definitions:

PLUG Alpha label indicating that the well is automatically recompleted whenever steam rate exceeds smax. When the well has just one active perforation, the check is against smaxl instead of smax. Recompletion consists of plugging the perforation with the highest steam rate. If there is only one perforation, the well is permanently shut in. Once a perforation has been plugged, it never produces/injects again, unless the well is reperforated by an FPERF card.

SHUTIN Alpha label indicating that the well is automatically shut in whenever the steam rate exceeds smax. It periodically is tested according to data on the TEST card. If steam rate is found to be less than smax during a test, the well is returned to production.

SOR Alpha label indicating that the PLUG and SHUTIN options apply to steam-oil ratio instead of steam rate.


smax Limiting steam production rate, STB(CWE)/D (STM3(CWE)/D),or steam-oil ratio, STB(CWE)/STB (STM3(CWE)/STM3), depending on the option selected.

smaxl Limiting steam rate or steam-oil ratio for wells with only one active perforation. Available only for the PLUG option. This entire card may be omitted, in which case the default is smaxli = smaxi.

NOTE: 1. One and only one of the PLUG or SMAXL SHUTIN labels must be specified.

5000.4.4 3-135


2. The number of smax and smaxl values must equal the number of wells in the well list. None of these restrictions is applied to wells not named on a WLIMIT card.


4. SLIMIT data may not be specified for injection wells.

5. Steam-oil ratios are specified in units of STB(CWE)/STB (STM3 [CWE]/STM3). (CWE = cold water equivalent.)

6. Specifying a SLIMIT card for a shut-in well will cause the well to be "turned back on".

Example:

TIME 5CSLIMIT SHUTIN SOR1 -252 267 -323 327 -364 390 -428 252*.99 57*.99

38*.99 39*.99 C

3.5.5 Economic Limit (ECOLIM)

An ECOLIM card is required to define the units being used for data on the QMIN (minimum well rate) card.

WECOLIM O wl

GLIQUID

Definitions:

Alpha label indicating the minimum production/injection specified on the QMIN card is based on:

W Water, STB/D (STM3/D).

O Oil, STB/D (STM3/D).

G Gas, MSCF/D (SM3/D).

LIQUID Liquid, STB/D (STM3/D).

wl List of all wells with minimum rates specified in this manner (see Section 1.5.2).

NOTE: 1. The ECOLIM card is used for both producers and injectors. One and

3-136 5000.4.4


only one of the W, O, G, or LIQUID labels must be specified. There is no default.

2. Specifying an ECOLIM card for a shut-in well will cause the well to be "turned back on".

3.5.6 Perforation Test Schedule (TSTPRF)

The TSTPRF card is used to specify the time interval between perforation tests. It is used in conjunction with the PRFLIM card.

TSTPRF tstpnc

Definition:

tstpnc Time interval between tests for violations of water cut or GOR by perforations, days. Default is 99,999 days.

NOTE: 1. Perforation tests are scheduled for the time at which the TSTPRF card is read plus tstpnc days. Until the simulation reaches that time, the perforation water cuts and GORs are unrestricted. Timesteps are not adjusted to hit the test time exactly. Once a set of tests is performed, new tests are scheduled for a time that is tstpnc days farther into the simulation. A tstpnc value of zero causes the program to test during every timestep.

2. Flashes to surface conditions are required for each perforation during these tests. This could cause a significant increase in computer time if frequently performed.

3. Both the TSTPRF and PRFLIM cards are needed to activate the option to check each active perforation for violations of water cut or GOR limits.

4. The TSTPRF card is also used to activate the recompletion unit option.

5000.4.4 3-137


3.5.7 Perforation Water Cut, GOR, and/or SOR Limits (PRFLIM)

The PRFLIM card is used to assign water cut, GOR, and/or SOR (steam oil ratio, VIP-THERM only) limits to be applied to each well perforation. Perforations will be shut in if they exceed the limits and a TSTPRF card is active. Note that the last perforation open is subject to the well constraints (WLIMIT/GLIMIT/SLIMIT) not the layer constraints.

PRFLIM wl GOR (PLUS) gorlim1 gorlim2 . . . gorlimnWCUT (PLUS) wctlim1 wctlim2 . . . wctlimnSOR sorlim1 sorlim2 . . . sorlimn

Definitions:

wl List of production wells for which limiting water cut and/or GOR values are being specified (see Section 1.5.2).

GOR Alpha label indicating that the values on this card are the limiting GOR values for each well in the well list.

PLUS Alpha label indicating that when a perforation is shut in due to the GOR limit, all perforations in the list before the shut-in one will also be shut in.

gorlim GOR limit to be applied to each perforation in this well, SCF/STB (SM3/STM3). Default is -1.0, meaning the well’s perforations will not be checked.

WCUT Alpha label indicating that the values on this card are the limiting water cut values for each well in the well list.

PLUS Alpha label indicating that when a perforation is shut in due to the water cut limit, all perforations in the list after the shut-in one will also be shut in.

wctlim Water cut limit to be applied to each perforation in this well. Default is -1.0, meaning the well’s perforations will not be checked.

SOR Alpha label indicating that the values on this card are the limiting steam-oil ratios for each well in the well list.

sorlim Steam-oil ratio limit to be applied to each perforation in this well. Default is -1.0, meaning the well’s perforations will not be checked.

NOTE: 1. The number of gorlim/wctlim and/or sorlim values must each equal the number of wells in the well list.

3-138 5000.4.4


2. Any combination of GOR, WCUT, and SOR cards may be specified.

3. Flashes to surface conditions are required for each perforation during these tests. This could cause a significant increase in computer time if frequently performed.

4. Specifying a PRFLIM card for a shut-in well will cause the well to be "turned back on".

5. The units of steam-oil ratio are STB(CWE)/STB (STM3(CWE)/STM3). (CWE = cold water equivalent.)

3.5.8 Minimum Rate (QMIN)

The QMIN card must be preceded by an ECOLIM card (Section ).

A QMIN card is used to define the minimum rate a well is allowed to produce/inject. When the rate falls below this qmin value, the well is shut in. The rate will only be checked to see if qmin is exceeded, thereby returning the well to production/injection, based on TEST card data.

QMIN wl qmin1 qmin2 . . . qminn

Definitions:

wl List of wells for which qmin values are being specified (see Section 1.5.2).

qmin Minimum rate at which the well is allowed to produce/inject. Units are determined by the ECOLIM card. Default is zero.

NOTE: 1. The number of qmin values must equal the number of wells in the well list.

2. Specifying a QMIN card for a shut-in well will cause the well to be "turned back on".

5000.4.4 3-139


3.5.9 Multiple Rate (QMULT)

Must be preceded by a PROD card (Section 3.4.1)

A QMULT card is required for a well to flow if the MULTRT option was specified on the PROD card. The QMULT card defines the maximum surface rates of all three phases for each well, from which a total reservoir volume rate will be computed and used as the maximum rate constraint.

A QMULT card may also be used to specify maximum surface rates for producer well types W, O, G, or LIQUID. The appropriate phase rate(s) will be used depending on the well type.

QMULT wl omax1 omax2 ... omaxn gmax1 gmax2 ... gmaxn wmax1 wmax2 ... wmaxn

Definitions:

wl List of production wells for which maximum rates are being specified (see Section 1.5.2).

omax Specified oil rate for the well. Units are STB/D (STM3/D).

gmax Specified gas rate for the well. Units are MSCF/D (SM3/D).

wmax Specified water rate for the well. Units are STB/D (STM3/D).

NOTE: 1. For a MULTRT well, the specified surface rates will be converted internally to reservoir barrel rates and summed to obtain a maximum reservoir barrel rate for total fluid at reservoir conditions. The well will produce at this maximum rate unless this causes a violation of one of the constraints (pressure, water cut, or gas-oil ratio constraints, but not rate constraints) defined by the user. In this event, the constraint is observed, causing a rate reduction. The conversion to a reservoir barrel rate is calculated at the start of each timestep.

2. The number of omax, gmax, and wmax values must each equal the number of wells in the well list.

3-140 5000.4.4


3.5.10 Injection Gas Composition (YINJ)

The YINJ card is used to specify the composition of the injected gas for injection wells using the STD or RES options and not identified as MI wells (with MI plant in the major gas sales option).

YINJ wlyinj1 yinj2 . . . yinjn orYINJ wlPROD

GATHER

FLOSTA

AREA

FIELD

Definitions:

wl List of wells for which yinj values are being specified (see Section 1.5.2).

yinjk The mole fraction of component k in the gas injection stream. A value must be specified for each of the n components, and the values must sum exactly to 1.0.

n The number of hydrocarbon components in the gas phase. Equal to ncv for VIP-THERM, equal to nc otherwise.

PROD Alpha label indicating that the injection composition is to be equal to the produced gas composition of the member of the indicated well management level in which the well resides. The alpha labels for the well management levels are:GATHER This is the default if no level entered.FLOSTA Flow station.AREA Area.FIELD Field.

NOTE: 1. A YINJ card must be entered to define the injected gas composition for all injection wells that are using the STD or RES options, except for those wells identified as MI wells in the major gas sales option (see Section 4.5).

2. The specified gas composition or the PROD option applies to all the wells in the well list.

5000.4.4 3-141


3. As many data cards as necessary may be used to specify a yinj value for each component.

Example:

CINJ G STD 253 -266 324 -326 365 -381YINJ 253 -266 324 -326 365 -381

0.9944 0.0056

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3.5.11 Define Additional Injection Gas Composition (YINJA)

The YINJA card is used to specify gas composition for injection wells using the INJA card.

YINJA wlyinja1 yinja2 . .. yinjanc

Definitions:

wl List of wells for which yinja values are being specified (see Section 1.5.2).

yinjak The mole fraction of component k in the additional gas injection stream. A value must be specified for each of the n components and the values must sum exactly to 1.0.

n The number of hydrocarbon components in the gas phase. Equal to ncv for VIP-THERM, equal to nc otherwise.

NOTE: If the INJA card is specified for a gas injection well, but the YINJA card is not specified for that well, the production composition from the specified well management hierachy, or the composition specified by the YREINJcard, is used for the well. If the YINJA composition is specified, the rate weighted composition is used.The YINJA card cannot be used for the FRES gas injection well using the general injection option.

3.5.12 Injection Water Salinity (WSAL)

The WSAL card is used to specify the water salinity of injection wells.

WSAL wlwsal1 wsal2 . .. wsaln

Definitions:

wl List of injectin wells for which wsal values are being specified (see Section 1.5.2).

wsal Water salinity, user-specified units. Default is 0.

NOTE: 1. The number of wsal values must equal the number of wells in the well list.

5000.4.4 3-143


3.5.13 Time Interval Between Tests

All wells that have been automatically shut in (pressure limit violation, lack of mobility, rate limit violation) are tested periodically to determine whether they can be returned to production/injection. The TEST (or WTEST) card is used to specify the time interval between tests for each type of shut-in well. The previous format for the TEST card is still accepted. See Note 1 below.

3.5.13.1 Global Specification (TEST)

When the TEST card is input, two methods are available to determine the time at which wells are tested:

1. all wells of the appropriate shut-in type tested at the same time and

2. each well is tested at the time interval after it was shut-in.

The first method is the default; the second method is invoked if any of the three values tincp, tincm, or tincr is negative.

TEST PRESSURE MOBILITY RATEtincp tincm tincr

Definitions:

PRESSURE Alpha label indicating that the corresponding value on the next card is the test increment for pressure shut-ins.

MOBILITY Alpha label indicating that the corresponding value on the next card is the test increment for mobility shut-ins.

RATE Alpha label indicating that the corresponding value on the next card is the test increment for rate shut-ins.

tincp Time interval between tests for shut-in wells due to a pressure limit violation, days. If the test card is not entered, the default is 0 days.

tincm Time interval between tests for shut-in wells due to lack of mobility, days. If the test card is not entered, the default is 0 days.

tincr Time interval between tests for shut-in wells due to a rate limit violation, days. If the test card is not entered, the default is 99,999 days.

NOTE: 1. When the prior input format of TEST tinc is used, the tincp, tincm, and tincr values are all set equal to tinc.

3-144 5000.4.4


2. A zero value for a time increment causes testing every timestep.

3. For the default method (positive values of tincp, tincm, and tincr), well tests are scheduled for the time at which the TEST card is read plus the appropriate shut-in type increment. Until the simulation reaches that time, shut-in wells will remain shut in. Timesteps are not adjusted to hit the test time exactly. Once the wells are tested, new tests are scheduled for a time that is the appropriate increment farther into the simulation.

4. For the second method (negative value of any of the three variables), each shut-in well is tested after the appropriate time interval (absolute value) has elapsed since it was shut-in. Timesteps are not adjusted to hit any test time exactly. If a well does not return to production/injection when tested, it will be retested at a time that is the appropriate increment farther into the simulation.

5. The TEST card data applies to all wells; i.e., it replaces any previously specified WTEST data.

3.5.13.2 Specification by Well (WTEST)

The WTEST card is used to specify the time interval between tests for individual wells. When this option is used, each well is tested at the time interval after it was shut-in.

WTEST wl(PRESSURE tincp1 tincp2 ... tincpn)(MOBILITY tincm1 tincm2 ... tincmn)(RATE tincr1 tincr2 ... tincrn)

Definitions:

wl List of wells for which time interval values are being specified (see Section 1.5.2).

PRESSURE Alpha label indicating that the values on this card are test increments for pressure shut-ins.

MOBILITY Alpha label indicating that the values on this card are test increments for mobility shut-ins.

RATE Alpha label indicating that the values on this card are test increments for rate shut-ins.

tinc p Time interval between tests for shut-in wells due to a pressure limit violation, days.

tincm Time interval between tests for shut-in wells due to a mobility limit violation, days.

5000.4.4 3-145


tincr Time interval between tests for shut-in wells due to a rate limit violation, days.

NOTE: 1. The number of tincp, tincm, and tincr values must equal the number of wells in the well list.

2. A zero value for a time increment causes testing every timestep.

3. Each shut-in well is tested after the appropriate time interval has elapsed since it was shut-in. Timesteps are not adjusted to hit any test time exactly. If a well does not return to production/injection when tested, it will be retested at a time that is the appropriate increment further into the simulation.

3.5.14 Fraction of Time That Well is on Stream (ONTIME)

Ontime factors do not apply to injection wells using either of the FSTD or FRES reinjection options.

The ONTIME card is used to specify the fraction of the time that a well is actually producing/injecting. The fraction is applied to the well rate after the rate has been determined by QMAX or pressure constraints and after the well minimum rate (QMIN), water cut (WLIMIT) and GOR (GLIMIT) checks.

Ontime factors may be input at the well level or at any other level of well management. The effective ontime factor for a well will be the one specified at the lowest level of the well hierarchy; that is, the first user-specified factor found in this order:

1. the well,

2. the appropriate gathering center,

3. the appropriate flow station,

4. the appropriate area,

5. the field.

ONTIME WELL wl ontime1 ontime2 . . . ontimen

Definitions:

WELL Alpha label indicating that the data on this card applies to wells. See Section 4.2.2 for ontime factor input at other levels of well management.

3-146 5000.4.4


wl List of wells for which ontime factors are being specified (see Section 1.5.2).

ontime Fraction of time that the well is actually producing/injecting. Default is 1.0.

NOTE: The number of ontime values must equal the number of wells in the well list.

3.5.15 Well Permeability-Thickness Multiplier (WKHMULT)

The WKHMULT card is used to specify a multiplier to be applied to the perforation permeability-thicknesses of a well. The multiplication occurs immediately upon reading the data.

WKHMULT wlwkhm1 wkhm2 ... wkhmn

Definitions:

wl List of wells for which wkhm values are being specified (see Section 1.5.2).

wkhm Permeability-thickness multiplier.

NOTE: The number of wkhm values must equal the number of wells in the well list.

3.5.16 GOR Penalty (GORPEN)

The GOR penalty data is used to set limits on oil production rates of individual wells, based on their previous month’s average GOR.

The oil production rate limits for the specified wells will be

Oil Rate Limit Base GOR Maximum Rate LimitAverage GOR for the previous month---------------------------------------------------------------------=

but not larger than the maximum rate limit. The Base GOR is a parameter entered with the GORPEN card. The Maximum Rate Limit is specified with the QMAX, QMULT or other oil rate limiting option.

While any well has a Base GOR greater than zero, the time steps are automatically restricted to coincide with the end of each calendar month. The last day of each month is represented by 00:00:01 AM on 1/??/?? in DAY/MONTH/YEAR format. At the end of each month, the average GOR over the month is determined for each well and used thereafter when required.

5000.4.4 3-147


GORPEN wlbgor1 bgor2 . . . . . . bgorn(agor1 agor2 . . . . . . agorn)

Definitions:

wl List of wells for each gorpen values are being specified.

bgor Base GOR for the well, SCF/STB (SM3/STM3). A zero or negative value will turn the GOR penalty off for the well. Default is -1.0.

agor Initial average GOR for the previous month, SCF/STB (SM3/STM3). This value if entered will be used until the end of the current month. This entire card may be omitted, in which case the default is as follows:

If the GOR penalty for any well is in use, then the previous month’s average GOR for the wells will already have been calculated. This value will be used.

If this is the first GOR penalty data for any well, then the average GOR over the previous month will not be available. If the well has an oil rate the value will be set to the well’s GOR at the previous time step, otherwise agori = bgori.

NOTE: The GOR penalty data should normally be first introduced at the beginning of the month. If it is first entered in the middle of a month the average GOR calculated at the end of the month will be based on the production since the data was entered.

3.5.17 GOR Constraint (GORCON, GORLIM)

The GOR constraint data is used to automatically adjust production rates of individual wells to satisfy the input GOR constraints. This option cannot be used simultaneously with the GOR penalty option (GORPEN) in the same simulation run.

The new well rate limits for the specified wells will be

New rate limitRate limit at prev timestep--------------------------------------------------------------------------------------- Target GOR

Avg. GOR for the prev period----------------------------------------------

expo

=

The new rate limit shall not exceed the input maximum rate limit and the ratio calculated above may be bounded by a user-input minimum and/or maximum. This option can be applied to producers with QMAX or QMULT rate specifications and the frequencies for rate adjustments can be individually defined by the user.

3-148 5000.4.4


GORCON OFF

(MINFCT fctmin) (MAXFCT fctmax)

GORLIM wltgor1 tgor2 ... tgorn)(EXPONENT expo1 expo2... expon)(FREQUENCY freq1 freq2... freqn)

Definitions:

GORCON Alpha label indicating that the GOR constraint option is being specified. This card is not needed if no other keywords on the card are being entered.

OFF Alpha label indicating that the GOR constraint option is to be turned off for all wells, in which case the well rate constraints return to the input maximum rate limits.

MINFCT Alpha label indicating that the minimum rate ratio for all wells specified on GORLIM cards is being entered.

fctmin Minimum allowable rate ratio when well rate is being reduced. Must be positive and less than or equal to 1. Default is 0.5.

MAXFCT Alpha label indicating that the maximum rate ratio for all wells specified on GORLIM cards is being entered.

fctmax Maximum allowable rate ratio when well rate is being increased. Must not be less than 1. Default is 2.

GORLIM Alpha label indicating that the GOR constraints for producers are being entered.

wl List of wells for which GOR constraint values are being specified (see Section 1.5.2).

tgor Target GOR for producers, SCF/STB (SM3/STM3). A zero or negative value will turn the GOR constraint off for the well, causing the well rate constraint to return to the input maximum rate limit. Default is -1.0.

EXPONENT Alpha label indicating that the exponents in the well rate ratio equation are being entered.

expo Exponent in the equation for each well. Default is 1.0.

5000.4.4 3-149


FREQUENCY Alpha label indicating that the frequencies for well rate adjustments are being entered.

freq Frequency for well rate adjustments, days. Default is 0., meaning that the rate is adjusted every timestep.

3.5.18 Maximum Steam Rate for Producers (QSTMX) (VIP-THERM)

The QSTMX card must be preceded by a PROD card (Section 3.4.1).

The QSTMX card defines the maximum steam rate a well is allowed to produce. This rate constraint is optional and is applied in addition to any other maximum rate constraints which may be defined.

QSTMX wlqstmx1 qstmx2 . . . qstmxn

Definitions:

wl List of wells for which qstmx values are being specified (see Section 1.5.2).

qstmx Maximum steam production rate at reservoir conditions in cold water equivalent surface units, STB(CWE)/D (STM3(CWE)/D).

3.6 Pressure Constraints and Productivity Indices

VIP-EXECUTIVE calculates a flowing bottomhole pressure consistent with the well index and well rate. This bottomhole pressure is checked against any user-defined pressure constraints. If the flow rate is in violation of a pressure constraint, it is altered accordingly and a new corresponding well rate is calculated. This bottomhole pressure is then used to allocate production/injection to individual gridblocks.

Bottomhole pressure constraints are defined by BHP cards. Alternatively, tubinghead pressure constraints can be imposed to control well flow. These are established by entering both THP cards and BHPTAB data. Hydraulics tables (BHPTAB data) are used for three-phase producers to relate tubinghead pressure to bottomhole pressure, flow rate, water cut, and gas-liquid ratio. VIP-EXECUTIVE searches for the largest intersection of the Inflow and Outflow Performance Curves (Figure 3-1). The bottomhole pressure corresponding to this intersection is used to calculate well phase rates.

Tubinghead pressure constraints can also be imposed on gas producers and on gas and water injectors. For these cases the default algorithm is based on the "average pressure and temperature method" as described by Beggs (Reference 1). For gas and water injectors hydraulics tables (BHITAB data) may alternatively be entered.

3-150 5000.4.4


Bottomhole pressure can also be constrained by the DPBHMX card, which defines a maximum drawdown (for producers) or buildup (for injectors) in each well. The drawdown/buildup is computed as the difference between a well’s average gridblock pressure at datum and the well’s bottomhole pressure. This option is applicable whether a well is on a BHP or THP constraint. If necessary, the bottomhole pressure of the well is reset so that the drawdown, or buildup, does not exceed DPBHMX. A new corresponding well rate is then calculated. To help alleviate convergence problems, after ITNSTP iterations (producers) or ITNSTQ iterations (injectors) the bottomhole pressure of DPBHMX constrained wells is fixed for the remainder of the timestep.

Hydraulics For A GivenTubinghead Pressure

Figure 3-1: Tubinghead Pressure

Whenever BHP or THP constraints are imposed, VIP-EXECUTIVE must calculate a flowing bottomhole pressure, fbhp. Productivity/injectivity indices are used to relate well flow rates to fbhp. In the VIP-EXECUTIVE family of simulators this is accomplished through a well index, WI. The well index is defined by its use within the following oil production equation:

qo 0.001127WIkh kro

Boo

---------------I

I 1=

L

Pbl Pbho– Dl Do– – .=

where

qo Oil phase production rate.

Pbho Datum flowing bottomhole pressure.

WI Well index.

5000.4.4 3-151


khl Permeability-thickness as defined by the FPERF card opposite the l-th perforation of the well. This need not be the gridblock value.

krol Relative permeability to oil at the gridblock saturation.

Bol Oil formation volume factor at Pbl.

ol Oil viscosity at Pbl.

Pbl Gridblock pressure of the cell containing the l-th perforation.

Average fluid density over the perforated interval of the well, based on production or injection fluids.

Dl Subsea depth of the l-th perforation.

Do Datum depth.

Since qo is known (the value defined by the QMAX card), Equation can be solved for flowing bottomhole pressure at datum, Pbh

o .

Therefore, the flowing bottomhole pressure at the reference depth is given by:

Pbho

WIkh kro

Boo

---------------I

Pbl Dl Do– – qo 0.001127–

I 1=

L

WIkhkro

Boo

-------------I

I 1=

L

--------------------------------------------------------------------------------------------------------------------------=

This value of Pbho is then compared to the user-specified bhp value. If Pbh

o is greater than bhp, the pressure constraint is honored and Pbh

o is set equal to bhp. A new qo is then calculated using Equation . (Similar expressions are used for gas and water.)

The data cards described in this section provide alternate ways to introduce the well index into the recurrent data stream. If no THP or BHP limits are to be established for a well, then no WI, PI, or RFLOW cards should be entered for that well. If previous limits are to be removed, wi should be set to zero by a WI card.

In VIP-THERM, if KHWI is entered in the FPERF data (Section 3.2.2), then no WI, PI, or RFLOW data should be entered since the well index is included in KHWI.

If no productivity/injectivity index (PI, WI, RFLOW, KHWI (VIP-THERM)) is specified, the well index defaults to zero. In this case, the simulator produces/injects the specified maximum production/injection rate without regard to pressure limitations. Allocation to different perforations is made on the basis of fluid mobility. This is reasonable only if Pbl - Pbhl is approximately constant for

3-152 5000.4.4


all layers; however, it may cause convergence difficulties in many cases. It is strongly recommended that a productivity/injectivity index be specified for each well.

5000.4.4 3-153


3.6.1 Well Index (WI)(Skip if PI or FLOW orWIL or KHWI is used)

The WI card is used to specify well indices for wells. Data specified on a WI card will replace any previous WI, PI, or RFLOW data for the same well. WIL values computed for a well by a previous FPERF card will be replaced by WI data for the same well.

WI (NORESET) wl wi1 wi2 . . .win

Definitions:

NORESET Alpha label indicating that the well and perforation cumulative reservoir production arrays (for the wells in the following list), used in conjunction with the WI multiplier tables (Section 3.19.2), should not be reset to zero with the input of new WI data. Default is to zero out these arrays.

wl List of wells for which wi values are being entered (see Section 1.5.2).

wi Well index, dimensionless.

wi2

lnrb

rw

----- skin+

--------------------------------- ,=

where

rb Equivalent radius (Peaceman) of the gridblock containing the well (see RFLOW Card) in ft (m).

rw Wellbore radius.

skin Skin factor.

NOTE: The number of wi values must equal the number of wells in the well list.

Example:

WI 4 -541538*0.52

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3.6.2 Productivity/Injectivity Index (PI) (Skip if WI or RFLOW or WIL or KHWI is used)

The PI card is used to specify productivity/injectivity data for wells. Data specified on a PI card will replace any previous WI, PI, or RFLOW data for the same well. WIL values computed for a well by a previous FPERF card will be replaced by PI data for the same well.

PI (NORESET) wl gf1 gf2 . . .gfn pi1 pi2 . . .pin

Definitions:

NORESET Alpha label indicating that the well and perforation cumulative reservoir production arrays (for the wells in the following list), used in conjunction with the WI multiplier tables (Section 3.19.2), should not be reset to zero with the input of new PI data. Default is to zero out these arrays.

wl List of wells for which gf and pi values are being entered (see Section 1.5.2).

gf Geometry factor. Converts the productivity/injectivity index from a drainage radius basis to a gridblock basis. Dimensionless.

For laminar, radial flow,

gf

ln re rw ln rb rw -----------------------=

where

re Drainage radius.

rb Equivalent radius (Peaceman) of the gridblock containing the well (see RFLOW Card) in ft (m).

rw Wellbore radius.

pi Productivity/injectivity index. Units are determined by the units of production or injection rates defined by the PROD or INJ cards:

5000.4.4 3-155


STB/D-psia (STM3/D-kPa) - Water, oil, or liquid STD producer, or a water injector with the STD or FSTD option.

MSCF/D-psia (SM3/D-kPa) - Gas STD producer or a gas injector with the STD or FSTD option.

rb/D-psia (m3/D-kPa) - Producer with the ALL or RES option or an injector with the RES or FRES option.

NOTE: 1. The number of gf and pi values must equal the number of wells in the well list.

2. PI data replace WI or RFLOW data. If none of these is read for any well, it produces/injects at the rate given on the QMAX card.

3. The pi is converted to wi (for internal program use) when the well is first put on production/injection. For an oil producer:wi pi gf

0.001127khkro

oBo

-------------I

I 1

L

-----------------------------------------------------=

3.6.3 Radial Flow Equation Data (RFLOW) (Skip if WI or PI or WIL or KHWI is used)

The RFLOW card is used to specify radial flow equation data for wells. Data specified on an RFLOW card will replace any previous WI, PI, or RFLOW data for the same well. WIL values computed for a well by a previous FPERF card will be replaced by RFLOW data for the same well.

RFLOW (NORESET) wl rw1 rw2 . . .rwn rb1 rb2 . . .rbn skin1 skin2 . . .skinn

Definitions:

NORESET Alpha label indicating that the well and perforation cumulative reservoir production arrays (for the wells in the following list), used in conjunction with the WI multiplier tables (Section 3.19.2), should not be reset to zero with the input of new RFLOW data. Default is to zero out these arrays.

wl List of wells for which rw, rb, and skin values are being entered (see Section 1.5.2).

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rw Wellbore radius, ft (m).

rb Equivalent radius (Peaceman) of the gridblock containing the well, ft (m). If this value is set to zero rb is defaulted (see note 3).

skin Skin factor. Dimensionless.

5000.4.4 3-157


wi

lnrb

rw

----- skin+

---------------------------------=

NOTE: 1. The number of rw, rb, and skin values must equal the number of wells in the well list. These values are used to calculate the well index and must result in a positive well index. The program calculates wifrom the data as follows:

The term is calculated from the data entered on the FLOANG card. If

not entered, = 2 .

2. The RFLOW data replace PI or WI data. If none of these is read for any well, it produces/injects at the rate given on the QMAX card.

3. When rb is entered as zero, its value is defaulted to that recommended by Peaceman (Reference 2), for wells located in the center of rectangular gridblocks with isotropic permeabilities:

rb 0.14 x2 y

2+

1 2=

For other configurations, e.g., wells in cross-sections, wells at gridblock corners, the correct value of rb, must be entered explicitly.

rb can only be defaulted for vertical wells in non-radial systems; i.e. the WELL keyword must contain IW and JW data. To obtain a defaulted value of rb for non-vertical wells or wells in a radial systems, the FPERF keyword must be used. Also wells with anisotropic permeablilities or other conditions that require the rb to vary by layer should make use of the FPERF keywork to define or default the values of rb.

3.6.4 Well Angle Open to Flow (FLOANG)

The FLOANG card is used to define the angle open to flow for wells.

FLOANG wlwang1 wang2...wangn

Definitions:

wl List of wells for which wang values are being entered (see Section 1.5.2).

wang Well angle open to flow, degrees. Values allowed are 0o to 360o, inclusive. Default is 360o.

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NOTE: The number of wang values must equal the number of wells in the well list.

3.6.5 Well Datum Depth (WLWDAT)

The WLWDAT card is used to assign the depth to which the flowing and limiting bottomhole pressures are referenced.

WLWDAT wlwdat1 wdat2 ... wdatn

Definitions:

w1 List of wells for which wdat values are being entered (See Section 1.5.2).

wdat Well datum depth, (ft)m. Bottomhole pressure is referenced to this depth. If not entered, datum depth defaults to the DEPTH from the first IEQUIL card. A value of zero causes wdat to be set to the depth to the center of the gridblock containing the first perforation.

NOTE: The number of wdat values must equal the number of wells in the well list.

3.6.6 Bottomhole Pressure (BHP)

To invoke BHP constraints, the user must define a productivity/injectivity index (Section 3.6). The BHP card allows the user to define a limiting bottomhole pressure.

BHP wl bhp1 bhp2 . . .bhpn

Definitions:

wl List of wells for which bhp values are being entered (see Section 1.5.2).

bhp Limiting bottomhole pressure, psia (kPa); i.e., minimum allowed pressure for a producer or maximum allowed pressure for an injector. Default is 0 psia for producers and 10,000 psia for injectors.

5000.4.4 3-159


NOTE: 1. The number of bhp values must equal the number of wells in the well list.

2. If both BHP and THP constraints have been entered for a well, both will be honored.

3. The bottomhole pressure printed in well reports is referenced to a depth of wdat (see WLWDAT card, Section 3.6.5) which must be measured from the same reference point as is used for gridblock depths.

4. If no THP or BHP limits are to be established, then no WI, PI, or RFLOW cards should be entered for the affected wells. If previous limits are to be removed, pi should be set to zero by a PI card. Note that inputting a wi value of zero on the WI card will shut in the well because of no mobility.

Example:C set the BHP to a minimum of 500 psi at 8800 feetBHP 1 -150

150*500.WLWDAT 1 -150

150*8800

3.6.7 Tubinghead Pressure (THP)

To invoke THP constraints with wellbore hydraulics tables for multiphase producers, the user must define a productivity index (Section 3.6), BHPTAB data, and ITUBE data. To invoke THP constraints with wellbore hydraulics tables for injectors, the user must define an injectivity index (Section 3.6), BHITAB data, and ITUBE data. To invoke single-phase THP constraints for injectors, the user must define an injectivity index, DIAM data, and TUBE data. To invoke THP constraints for gas producers, the user must define a productivity index (Section 3.6), DIAM data, GTHPWL data, and THPGTB data. The THP card allows the user to define a limiting tubinghead pressure.

THP wl thp1 thp2 . . . thpn

Definitions:

wl List of wells for which thp values are being entered (see Section 1.5.2).

thp Tubinghead pressure limit, psia (kPa); i.e., minimum pressure for producers or maximum pressure for injectors.

NOTE: 1. The number of thp values must equal the number of wells in the well

3-160 5000.4.4


list.

2. If both BHP and THP constraints have been entered for a well, both will be honored.

3. If no THP or BHP limits are to be established for a well, then no WI, PI, or RFLOW cards should be entered for that well. If previous limits are to be removed, wi should be set to zero.

4. For predictive well management, tubinghead pressure values for production wells should be input for each eligible pressure system.

The following statements are true when implicit tubinghead pressure equations are not used. For both three-phase and gas producers, the tubinghead pressure algorithm is only performed during the first "few" outer iterations of the timestep (ITNTHP card). During the rest of the timestep the well is treated as a bottomhole pressure constrained well, with bhp equalling the calculated value from the tubinghead pressure algorithm.

3.6.8 Implicit Tubinghead Pressure Equations (IMPTHP)

The IMPTHP card is used to specify whether implicit tubinghead pressure equations are to be set up when a well is constrained by a tubinghead pressure limit (THP).

IMPTHP ON

OFF

Definitions:

ON Alpha Label indicating that implicit tubinghead pressure equations are to be set up.

OFF Alpha label indicating that implicit tubinghead pressure equations are not to be set up. This is the default.

NOTE: The tubinghead pressure iteration control variable, ITNTHP, is ignored when implicit tubinghead pressure is on.

3.6.9 Tubinghead Pressure Iteration Control (ITNTHP)

The ITNTHP card allows the user to specify the number of outer iterations of each timestep during which the tubinghead pressure algorithm will be performed. After this number the wells are treated as bottomhole pressure controlled, with bhp equalling the calculated value from the itnthp iteration.

5000.4.4 3-161


ITNTHP itnthp

Definition:

itnthp Number of outer iterations of each timestep during which the tubinghead pressure algorithm for producers will be performed. Default is 2.

NOTE: This value is ignored when implicit tubinghead pressure equations are in use (IMPTHP ON).

3.6.10 Maximum Drawdown Constraint (DPBHMX)

The DPBHMX card allows the user to define a limiting drawdown or buildup pressure.

DPBHMX wl dpbhmx1 dpbhmx2 . . . dpbhmxn

Definitions:

wl List of wells for which dpbhmx values are being entered (see Section 1.5.2).

dpbhmx Limiting drawdown (producers) or buildup pressure (injectors), psia (kPa); i.e., maximum allowed difference between a well’s average gridblock pressure at datum and the well’s bottomhole pressure. Default is 10,000 psia.

NOTE: The number of dpbhmx values must equal the number of wells in the well list.The well’s average gridblock pressure is calculated over all the flowing perforations.To help alleviate convergence problems, after ITNSTP iterations (producers) or ITNSTQ iterations (injectors) the bottomhole pressure of DPBHMX constrained wells is fixed for the remainder of the timestep.

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3.7 Wellbore Crossflow Model

3.7.1 Crossflow Option (XFON/XFOFF) (Not available in VIP-THERM)

Wellbore crossflow is computed using the method of Modine, Coats, and Wells (Reference 9).

The XFON and XFOFF cards are used to select crossflow computations by well. The computations can be enabled or disabled at any time. Crossflow is off by default.

XFON (QMX) wlXFOFF wl

Definitions:

XFON Keyword indicating that wellbore crossflow computations are to be performed for the following list of wells.

XFOFF Keyword indicating that wellbore crossflow computations are not to be performed for the following list of wells.

QMX Keyword indicating that the wellbore crossflow computations for each of the wells in the following list will not occur until the well has a QMAX > 0.

wl Well list (see Section 1.5.2).

NOTE: 1. Print control for the wellbore crossflow summary is equivalent to that for the Well Perforation Summary (WLLYR). When the Well Perforation Summary is printed, the Wellbore Crossflow Summary is printed which shows crossflow rates by phase and perforation in units of rb/D (rm3/D) for all wells which are currently crossflowing. Crossflow rates are not included in the Well Perforation Summary.

2. If XFON is specified for one or more wells the simulator will compute the wellbore gradient using the volume balance method (MBAWG = OFF).

5000.4.4 3-163


3.7.2 Wellbore Gradient Calculation (MBAWG)

Two methods are available for calculating wellbore gradients. In the first method (default, except as indicated below), an average value of the wellbore gradient over the perforated intervals is calculated by "mobility allocation" as

GRAD

WI*KH Ikrjj

j

-----------

j 1=

Np

II 1=

L

WI*KH Ikrj

j

------

j 1

Np

I 1

L

---------------------------------------------------------------=

where L is the number of layers, Np is the number of phases, WI and KH are the well index and permeability-thickness products by layer, and krj, j, and j are phase relative permeabilities, densities, and viscosities.

In the second method, a value for the wellbore gradient opposite each perforated interval is calculated by a wellbore volume balance. These calculations include the effects of crossflowing layers but ignore interphase mass transfer effects and fluid expansion in the wellbore. This method is the default, and cannot be overridden, if either the crossflow option is invoked or the horizontal/inclined wellbore flow correlation (see note 9 in Section 3.2.2) is invoked.

The MBAWG card is used to control the wellbore gradient calculations.

MBAWG ON

OFF

Definitions:

ON Use mobility allocation method for the average wellbore gradient. This is the default.

OFF Use the volume balance method for the wellbore gradient.

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3.7.3 Wellbore Gradient Calculation (VIP-THERM)

In VIP-THERM, three methods of calculating wellbore gradients are available. For production wells, a fourth option is specification of gradient by perforation in the FPERF data (Section 3.2.2). Two of the calculational options, MOBAVG and VOLBAL, are described in the previous section, the data for which is also accepted in VIP-THERM. The default (except as indicated below) in VIP-THERM is similar to the MOBAVG option except that a gradient for each perforation is computed which is a mobility average gradient of the fluids produced at and below it:

GRADk

WI*KH Ikrjj

j

-----------

j 1=

p

II k=

WI*KH Ikrj

j

------

Np

L

---------------------------------------------------------------=

WBGRADMOBAVG

MOBAVB

VOLBAL

Definitions:

MOBAVG Use single mobility average gradient.

MOBAVB Use mobility average for each perforation based on all perforations below and including it. Default, except as indicated below.

VOLBAL Use volume balance method. This is the default if either the crossflow option or the inclined/horizontal wellbore flow correlation (see note 9 in Section 3.2.2) is invoked.

5000.4.4 3-165


3.8 Wellbore Flash Controls

The wellbore flash procedure is designed to calculate stock tank oil, water, and gas flow rates for each production well when a surface rate or a pressure constraint is specified by the user. An iterative procedure is applied to find a bottomhole pressure that honors the well boundary condition. The procedure is executed in each outer iteration of a timestep, and separator flash subroutines are called several times in each iteration of the procedure. These calculations require a significant amount of computer time in compositional models with many wells.

In order to minimize the work involved in these calculations, methods have been developed to improve the efficiency of calculations. The wellbore equations and the separator flash equations are now solved simultaneously. The initial bottomhole pressure is calculated from the wellbore equation with a separator coefficient defined in the previous outer iteration and values are only recalculated if necessary. The user can control iteration tolerances and decide whether simplified separator calculations will be performed.

The user may optionally choose to take into account pressure gradient variations with depth in production wells in the wellbore flash calculations.

3.8.1 THP Convergence Control (BHPITN)

The BHPITN card is used in conjunction with the THP, ITUBE, BHPTAB, and BHPADD cards. A BHPITN card with the first three parameters specified will apply to injection wells only. A card with the two additional parameters is used to set iteration and convergence parameters for tubinghead pressure and simplified separator computations in production wells.

BHPITN ibhpmx bhptlp bhptlq (P bhptlz)

Definitions:

ibhpmx Maximum number of tubinghead pressure iterations. Default is 100.

bhptlp Relative tolerance used to determine convergence of the bottomhole pressure calculation during THP iterations. Default is 0.0001.

bhptlq Relative tolerance used to determine convergence of the rate calculation during THP iterations. Default is 0.001 for producers and 0.0001 for injectors.

P Alpha label indicating that iteration and convergence parameters for tubinghead pressure and simplified separator computations for production wells are set.

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bhptlz Tolerance of composition changes. This parameter is used in the simplified composition calculations. If the maximum change of the mole fractions of the hydrocarbon components in an input stream of a separator battery is less than the tolerance bhptlz, the K-values in each stage of the battery are not recalculated. If this tolerance is set to zero, the K-values are recalculated in each outer iteration of each timestep. Default is 0.0 if number of components is 2; otherwise, 0.0005.

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3.9 Wellbore Hydraulics Tables

3.9.1 Wellbore Hydraulics Table Assignment (ITUBE)

ITUBE data must be defined along with BHPTAB data if a THP card is entered for a multi-phase producer. This input is optional for single-phase (water and gas) injectors and gas producers, for which simple wellbore hydraulics treatments are available.

The ITUBE data are used with the wellbore hydraulics table data (BHPTAB and/or BHITAB) to relate tubinghead pressure to bottomhole pressure.

ITUBE wl ibhp1 ibhp2 . . . ibhpn dzw1 dzw2 . . . dzwn

Definitions:

wl List of wells for which ibhp and dzw values are being entered (see Section 1.5.2).

ibhp Number of the bottomhole pressure table (BHPTAB/BHITAB card) that defines tubing pressure losses for this well. A zero here will turn off tubing calculations.

dzw Vertical distance from the wellhead to the first set of perforations, ft (m).

NOTE: 1. The number of ibhp and dzw values must equal the number of wells in the well list.

2. If dzw differs from the dzw value used to construct the bottomhole pressure table, a gravity head calculation is used to adjust from the perforations to the reference depth of the table.

3. The bottomhole pressure printed in well reports is referenced to a depth of wdat (see WLWDAT card, Section 3.6.5), which must be measured from the same reference point as is used for gridblock depths.

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Example:

ITUBE 2 -14 18 22 24 -37 4130*130*8800WLWDAT 2 -14 18 22 24 -37 4130*8800THP 2 -14 18 22 24 -37 4130*1815.C

3.9.2 Wellbore Hydraulics Table (BHPTAB)

Must be defined if THP data is entered for a multi-phase producer.

BHPTAB data are used to relate tubinghead pressure to bottomhole pressure and the three phase flow rates. Each table can be defined independently, and more than one well can refer to the same BHPTAB.

BHPTAB nbhp dzw QLIQQO q1 q2 . . . qkQGASQEWSGLRGOR g1 (g2 . . . gl)OGRWCUT w1 (w2 . . . wm)WGR(ALQ (GASRATE) alq1(alq2 . . .alqj))THP thp1 (thp2 . . . thpn)IGLR

IGORIWCUT IQLIQ

IQO(IALQ)BHP(ITHP)

IOGR IWGR IQGAS

IQEWS

ig1 iw1 iq1 (ialq1) bhp(ithp1)(bhp(ithp2). . .bhp(ithpn)). . . . . .. . . . . .. . . . . .igl iwm iqk (ialqj) bhp(ithp1)(bhp(ithp2). . .bhp(ithpn))

5000.4.4 3-169


Definitions:

nbhp Number of the bottomhole pressure table being read.

dzw Vertical distance from the wellhead to the reference point for bottomhole pressures as tabulated, ft (m).

QLIQ Alpha label indicating that values on this card are liquid rates (oil plus water). This must be used with GLR/GOR and WCUT.

QO Alpha label indicating that values on this card are oil rates. This must be used with GLR/GOR and WCUT.

QGAS Alpha label indicating that values on this card are gas rates. This must be used with OGR and WGR.

QEWS Alpha label indicating that values on this card are equivalent total wellstream rates (total hydrocarbon rate converted to gas rate at standard conditions). This must be used with OGR and WGR.

q Liquid or oil rates, STB/D (STM3/D), or gas rates, MSCF/D (SM3/D). Values can be unequally spaced.

GLR Alpha label indicating that values on this card are gas-liquid ratios. This must be used with either QLIQ or QO.

GOR Alpha label indicating that values on this card are gas-oil ratios. This must be used with either QO or QLIQ.

OGR Alpha label indicating that values on this card are oil-gas ratios. This must be used with either QGAS or QEWS.

g Gas-liquid or gas-oil ratios, SCF/STB (SM3/STM3), or oil-gas ratios, STB/MMSCF (STM3/KSM3). Values can be unequally spaced.

WCUT Alpha label indicating that water-cut values are read on this card. This must be used with either QLIQ or QO.

WGR Alpha label indicating that values on this card are water-gas ratios. This must be used with either QGAS or QEWS.

w Water-cut values, fraction, or water-gas ratios, STB/MMSCF (STM3/KSM3). Values can be unequally spaced.

ALQ Alpha label indicating that values on this card are either gaslift gas rates or user-defined artificial lift quantity values.

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GASRATE Alpha label indicating that the values on this card are gaslift gas rates. If this keyword is specified, then ALQ well data (Section 3.9.6) will be ignored and the gaslift gas rate for the well will be used instead. This also means that ratios on the GLR/GOR card consist of produced gas only, not total gas.

alq Gaslift gas rates, MSCF/D (SM3/D) or artificial lift quantity values, as defined by the user. Values can be unequally spaced.

THP Alpha label indicating that tubinghead pressures are read on this card.

thp Tubinghead pressure values, psia (kPa). Values can be unequally spaced.

IGLR Alpha label indicating that the values read in the column under this heading are gas-liquid ratio indices. This must be used with GLR.

IGOR Alpha label indicating that the values read in the column under this heading are gas-oil ratio indices. This must be used with GOR.

IOGR Alpha label indicating that the values read in the column under this heading are oil-gas ratio indices. This must be used with OGR.

IWCUT Alpha label indicating that the values read in the column under this heading are water-cut indices. This must be used with WCUT.

IWGR Alpha label indicating that the values read in the column under this heading are water-gas ratio indices. This must be used with WGR.

IQLIQ Alpha label indicating that the values read in the column under this heading are liquid rate indices. This must be used with QLIQ.

IQO Alpha label indicating that the values read in the column under this heading are oil rate indices. This must be used with QO.

IQGAS Alpha label indicating that the values read in the column under this heading are gas rate indices. This must be used with QGAS.

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IQEWS Alpha label indicating that the values read in the column under this heading are equivalent total wellstream rate indices. This must be used with QEWS.

IALQ Alpha label indicating that the values read in the column under this heading are artificial lift quantity indices. This must be used with ALQ.

BHP(ITHP) Alpha label indicating that the values read in the columns under this heading are bottomhole pressure values for each tubinghead pressure input. Parentheses must appear in this alpha label.

igl Index referring to the l-th ratio value read.

iwm Index referring to the m-th water-cut value read.

iqk Index referring to the k-th rate value read.

ialqj Index referring to the j-th gaslift rate or artificial lift quantity value read.

bhp(ithp) The bottomhole pressure value, psia (kPa), corresponding to the indicated ratio, water-cut, and rate values. The corresponding tubinghead pressure is the thp value that would correspond to ithp. The number of bottomhole pressure values on this card must equal the number of thp values on the THP card.

NOTE: An ITUBE value must be specified for each well which is to use one of the BHPTAB tables.

Example

C TUBING SIZE = 3.500 OD = 2.992 IDC SEPARATOR PRESSURES: 215. 315. 665. 665. 665.C FLOW LINE LENGTHS: 0. 0. 4000. 10000. 18000.C HALF WELL RATES TO REFLECT HALF WELLSBHPTAB 1 8800.QLIQ 50. 250. 500. 1000. 2000. 5000.GLR 300. 750. 1500. 5000. 20000.WCUT 0.000 0.500THP 215. 315. 815. 1315. 1815.C REMAINDER OF TABLE

3-172 5000.4.4


3.9.3 Wellbore Hydraulics Table Switching (NEWBHPTAB)

The NEWBHPTAB card allows the user to set alternate bottomhole pressure tables for a well when, at the existing THP limit, its rate becomes too low, its gas ratio becomes too high, and/or its water ratio becomes too high.

The definition and units of the RATE, GRATIO, and WRATIO data are the same as that specified in the corresponding bottomhole pressure table. This means the current table to which the well is assigned, not the one to which it might be switched.

NEWBHPTAB wlRATE

ibhp1 ibhp2 ... ibhpnq1 q2 ... qn

GRATIOjbhp1 jbhp2 ... jbhpng1 g2 ... gn

WRATIOkbhp1 kbhp2 ... kbhpnw1 w2 ... wn

Definitions:

wl List of wells for which table number and constraint values are being entered (see Section 1.5.2).

ibhp Bottomhole pressure table number to which the well will be assigned when its production rate (QLIQ/QO/QGAS/QEWS) falls below the corresponding q value.

q Threshhold production rate such that when the well’s production rate falls below this value, the bottomhole pressure table number will be changed. The unit of q is the same as that specified in the corresponding bottomhole pressure table (BHPTAB) to which the well is currently assigned.

jbhp Bottomhole pressure table number to which the well will be assigned when its gas ratio (GLR/GOR/OGR) exceeds the corresponding g value.

g Threshhold gas ratio such that when the well’s GLR/GOR/OGR exceeds this value, the bottomhole pressure table number will be changed. The unit of g is the same as that specified in the corresponding bottomhole pressure table (BHPTAB) to which the well is currently assigned.

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kbhp Bottomhole pressure table number to which the well will be assigned when its water ratio (WCUT/WGR) exceeds the corresponding w value.

w Threshhold water ratio such that when the well’s WCUT/WGR exceeds this value, the bottomhole pressure table number will be changed. The unit of w is the same as that specified in the corresponding bottomhole pressure table (BHPTAB) to which the well is currently assigned.

NOTE: 1. The number of ibhp, q, jbhp, g, kbhp, and w values must be equal the number of wells in the well list.

2. A bottomhole pressure table switch will occur at most once for each limit type. For example, once a switch is made for low production rate the well will not switch back to the original table if the rate rises back above the specified threshold value.

3. One, two, or all three sets of 3 lines of data may be entered under one NEWBHPTAB card. The same well list applies to the sets of data.

4. The prior form of this data (no headings, only one line each of table numbers and rates) is accepted and is interpreted as RATE data.

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3.9.4 Wellbore Hydraulics Table for Injectors (BHITAB)

Must be defined if ITUBE data is entered for an injection well for which THP data is also entered.

BHITAB data are used to relate tubinghead discharge pressure to bottomhole injection pressure and injection rate. Each table can be defined independently, and more than one well can refer to the same BHITAB. The phase being injected need only be specified if metric units are being used, in which case a units conversion must be performed.

BHITAB nbhi dzw W

G

QI qi1 qi2 ...qikTHP thp1 (thp2 ...thpn)IQI BHP ITHP ITHP BHP IQI

iqi1 bhp ithp1 (bhp ithp2 bhp ithpn

ithp1 bhp iqi1 bhp iqi2 bhp iqik

. . . . . .. . . . . . .. iqik bhp ithp1 (bhp ithp2 bhp ithpn

ithpn bhp iqi1 bhp iqi2 bhp iqik

Definitions:

nbhi Number of the bottomhole injection pressure table being read.

dzw Vertical distance from the wellhead to the reference point for bottomhole injection pressures as tabulated, ft (m).

W Alpha label, for metric units input only, indicating that the rates are water injection rates, for appropriate units conversion.

G Alpha label, for metric units input only, indicating that the rates are gas injection rates, for appropriate units conversion.

QI Alpha label indicating that values on this card are injection rates.

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qi Injection rates, water, STB/D (STM3/D), or gas, MSCF/D (SM3/D). Values can be unequally spaced.

THP Alpha label indicating that values on this card are tubinghead injection pressures.

thp Tubinghead injection pressure values, psia (kPa). Values can be unequally spaced.

IQI Alpha label indicating that the values read in the column under this heading are injection rate indices.

BHP(ITHP) Alpha label indicating that the values read in the columns under this heading are bottomhole injection pressure values for each tubinghead injection pressure input. Parentheses must appear in this alpha label.

ITHP Alpha label indicating that the values read in the column under this heading are tubinghead injection pressure indices.

BHP(IQI) Alpha label indicating that the values read in the columns under this heading are bottomhole injection pressure values for each injection rate input. Parentheses must appear in this alpha label.

iqik Index referring to the k-th injection rate value read.

bhp(ithp) The bottomhole injection pressure value, psia (kPa), corresponding to the indicated rate and tubinghead pressure values. The number of bottomhole pressure values on this card must equal the number of thp values on the THP card.

ithpn index referring to the n-th tubinghead injection pressure value read.

bhp(iqi) The bottomhole injection pressure value, psia (kPa), corresponding to the indicated rate and tubinghead pressure values. The corresponding injection rate is the qi value that would correspond to iqi. The number of bottomhole pressure values on this card must equal the number of qi values on the QI card.

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Examples:

BHITAB 1 9400.QI 1 500 1000 2000 3000 4000 5000 6000 7000 8000THP 15. 200 500 1000ITHP BHP(IQI)1 4304 4297 4276 4219 4134 4017 3854 3681 3471 32192 4489 4482 4467 4404 4319 4202 4039 3866 3656 34043 4789 4776 4759 4706 4624 4504 4349 4166 3956 37044 5289 5272 5249 5186 5106 5004 4859 4679 4456 4204

3.9.5 Additive Correction to BHP Tables (BHPADD)

This card is used in conjunction with the THP, ITUBE, and BHPTAB cards.

The BHPADD card is used to provide an additive correction term to the value of bottomhole pressure obtained from the BHP tables.

BHPADD wl bhpadd1 bhpadd2 . . . bhpaddn

Definitions:

wl List of production wells for which bhpadd values are being specified (see Section 1.5.2).

bhpadd Additive correction to apply to the value of bottomhole pressure obtained from the BHP tables for the well, psi (kPa). Value may be positive or negative. Default is 0.0 psia.

NOTE: The number of bhpadd values must equal the number of wells in the well list.

3.9.6 Artificial Lift Quantity (ALQ)

The ALQ card is used to specify an artificial lift quantity, which can be used as an additional parameter in the interpolation of the BHPTAB tables. If the ALQ parameter in the BHPTAB is table for a well is specifically identified as gaslift GASRATE, then the ALQ data for that well is not required and will not be used if entered.

ALQ wlalq1 alq2 ... alqn

Definitions:

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wl List of production wells for which alq values are being specified (see Section 1.5.2).

alq Artificial lift quantity value for the well. Units are defined by the user. Default is 0.0.

NOTE: The number of alq values must equal the number of wells in the well list.

3.10 Gas Producers

The algorithm for gas producers described below is activated for a well by assigning a gas producer THP table to the well (GTHPWL card). If this table is not assigned, the algorithm described in the Wellbore Hydraulics section (Section 3.9) is used.

The algorithm implemented in VIP-EXECUTIVE for handling tubinghead pressure constraints for gas producers is based on the "average pressure and temperature method" as described on pp. 103-104 of Gas Production Operations by H. Dale Beggs (Reference 1). (Note that the algorithm for tubinghead pressure constraints for gas and water injectors also is based on this method.) Generally speaking, the rate and corresponding bottomhole pressure of a constrained well occurs at the intersection of the inflow and outflow performance curves for the well. To calculate the flowing bottomhole pressure for the outflow performance curve:

1. divide the wellbore into equal-length intervals,

2. starting at the wellhead, determine the bottomhole pressure of the first interval using the input tubinghead pressure constraint and other properties,

3. use the bottomhole pressure of the first interval as the tubinghead pressure of the second interval to calculate the bottomhole pressure of the second interval,

4. continue this process until the bottomhole pressure of the last interval is calculated; this is the flowing bottomhole pressure of the well for the outflow curve.

Properties needed by the "average pressure and temperature method", and their source in VIP-EXECUTIVE, are as follows:

1. Gas flow rate - constant over entire wellbore.

2. Average temperature - linear interpolation between surfacetemperature on GASTHP card and reservoirtemperature TRES.

3. Average z-factor and average viscosity - table lookup in THPGTB table at interval tubinghead pressure and temperature.

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4. Inside diameter of tubing and tubing roughness factor - DIAM card

5. Effective tubing length and vertical distance from wellhead to first set of perforations - TUBE card

6. Gas gravity - mol·. wt. j* production composition j 28.96

j 1=

NC

The TUBE and DIAM cards (Section 3.11.1 and 3.11.2) as described for injectors must be specified for gas producers that will use tubinghead pressure constraints.

The BHPITN card (Section 3.8.1) may optionally be specified.

3.10.1 Assignment of Gas Producer THP Tables (GTHPWL)

GTHPWL wl ithgtb1 ithgtb2 . . . ithgtbn

Definitions:

wl List of wells for which tables are being assigned (see Section 1.5.2).

ithgtb Number of the gas producer THP table (THPGTB card) that defines the z-factors and viscosities in the wellbore for this well.

NOTE: The number of ithgtb values must equal the number of wells in the well list.

3.10.2 Gas Well THP Calculation Data (GASTHP)

GASTHP INTERVALS

LENGTH

(SURFTEMP)(LGRMAX)

intthg

length

(stmthg)(lgrmax)

Definitions:

intthg Number of intervals into which the wellbore length will be divided. Default is 5.

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length Approximate length of each interval in the wellbore, ft (m).

stmthg Surface temperature in the wellbore at the wellhead, °F (°C). Default is TRES.

lgrmax Maximum allowed liquid-gas ratio for a gas producer using tubinghead pressure, STB/MMSCF (STM3/KSM3). Default is 10 STB/MMSCF.

3.10.3 Z-factor/Viscosity Tables for Gas Producer THP (THPGTB)

THPGTB itabPRESSURE pres1 pres2 . . . presk(TEMP temp1 (temp2 . . . tempm))IPRES (ITEMP) Z VISCip1 (it1) z1 visc1. . . .. . . .. . . .ipk (itm) zkm visckm

Definitions:

itab Number of the gas producer THP table being read.

PRESSURE Alpha label indicating that pressure values are read on this card.

pres Pressure values, psia (kPa). Values can be unequally spaced.

TEMP Alpha label indicating that temperature values are read on this card. This card is optional.

temp Temperature values, °F (°C). Values can be unequally spaced.

IPRES Alpha label indicating that the values read in the column under this heading are pressure indices.

ITEMP Alpha label indicating that the values read in the column under this heading are temperature indices. This label can be included only if a TEMP card was input.

Z Alpha label indicating that the values read in the column under this heading are z-factors.

VISC Alpha label indicating that the values read in the column under this heading are viscosities.

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ipk Index referring to the k-th pressure value read.

itm Index referring to the m-th temperature value read. This index can be included only if a TEMP card was input.

zkm The z-factor value corresponding to the indicated pressure (and temperature) value(s).

visckm The viscosity value corresponding to the indicated pressure (and temperature) value(s), cp (cp).

NOTE: If the pressure or temperature values cannot fit on one card, then continuation cards can be used; that is,

PRESSURE pres1 pres2. . .. . . presk

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3.11 Single Phase Injectors

The algorithm for single phase injectors described below is automatically used for such a well unless ITUBE data has been input for the well.

The algorithm implemented in VIP-EXECUTIVE for handling tubinghead pressure constraints for single phase injectors is based on the “average pressure and temperature method” as described on pp. 103-104 of Gas Production Operations by H. Dale Beggs (Reference 1).

3.11.1 Tubing Length Assignment (TUBE)

Must be defined if THP data are entered for an injector.

The TUBE data are used in conjunction with the DIAM data to relate tubinghead pressure to bottomhole pressure.

TUBE wl tl1 tl2 . . . tln dzw1 dzw2 . . . dzwn

Definitions:

wl List of wells for which tl and dzw values are being entered (see Section 1.5.2).

tl Effective tubing length, ft (m). Includes the equivalent tubing length of any downhole equipment.

dzw Vertical distance from the wellhead to the first set of perforations, ft (m).

NOTE: 1. The number of tl and dzw values must equal the number of wells in the well list.

2. The bottomhole pressure printed in well reports is referenced to a depth of wdat (see WLWDAT card, Section 3.6.5), which must be measured from the same reference point as is used for gridblock depths.

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3.11.2 Tubing Diameter/Friction Factor (DIAM)

Must be defined if THP data are entered for an injector.

The DIAM data are used in conjunction with the TUBE data to relate tubinghead pressure to bottomhole pressure.

DIAM wl diam1 diam2 . . . diamneps1 eps2 . . . epsn

Definitions:

wl List of wells for which diam and eps values are being entered (see Section 1.5.2).

diam Inside diameter of the tubing, inches (centimeters).

eps Tubing roughness factor, inches (centimeters).

NOTE: 1. The number of diam and eps values must equal the number of wells in the well list.

2. Friction factors are calculated by the Jain equation (Reference 3).

3.11.3 Specify Density and Viscosity Values (WTRTHP)

The WTRTHP card applies to water injectors on tubinghead pressure control.

The WTRTHP card is used to specify the density and viscosity values that are input to the "average pressure and temperature method" for water injectors on tubinghead pressure control. Internally calculated values are used if this data is not entered.

WTRTHP wl DENSITY dens1 dens2 . . . densn VISCOSITY visc1 visc2 . . . viscn

Definitions:

wl List of water injection wells for which dens and visc values may be specified (see Section 1.5.2).

DENSITY Alpha label indicating that the following values are water densities, gm/cc (gm/cc). Default is to compute a value internally.

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VISCOSITY Alpha label indicating that the following values are water viscosities, cp (cp). Default is to use the vw input on the constants card in VIP-CORE (Section 2.2.4).

NOTE: 1. The number of dens and visc values, if specified, must equal the number of wells in the well list.

2. Both the DENSITY and VISCOSITY cards need not be specified. The program will accept either one or both.

3.12 Pattern Balancing (Not available in VIP-THERM)

3.12.1 Pattern Balancing Option (PATTN)

The PATTN card is used to specify whether the pattern balancing option is to be used.

PATTN

ON

ATWAG

OFF

Defintions:

ON Alpha label indicating that the pattern balancing option is to be used.

ATWAG Alpha label indicating that the pattern balancing option with automatic WAG option is to be used. This option is currently compatible only with the miscible option.

OFF Alpha label indicating that the pattern balancing option will not be used. This is the default.

NOTE: The pattern balancing option is not compatible with the following options: the water voidage replacement option, the gas voidage replacement option, and the general injection region option.The PATNCI and PATNPP cards are required to define a pattern. The NPTNMX parameter on the DIM card is used to define the maximum number of patterns.Currently, the ATWAG option is only available with the miscible option. If the option is chosen, the ATWGVA, ATWGCL, and ATWGCT cards must also be entered.

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Example:

PATTN ON

3.12.2 Assign Central Injection Wells to a Pattern or Turn Off Pattern Balancing (PATNCI )

The PATNCI card is used to assign appropriate central injection wells to a pattern. Each central injection well can only be assigned to one pattern.

PATNCI npn WAG ratio

ATWAG tcycle

voidf wl

or

PATNCI npn WAG ratio

ATWAG tcycle

voidfnw lyrl(data card may be repeated as necessary)

or

PATNCI npnOFF

Definitions:

npn Pattern number to which the injection wells are assigned.

WAG Alpha label indicating that the injectors in a pattern are a pair of WAG injectors (one water injector and one gas injector).

ratio WAG ratio at reservoir conditions.

ATWAG Alpha label indicating that the injector in a pattern is an automatic WAG (explicit) injector.

tcycle Automatic WAG cycle period, months.

voidf Voidage factor for a pattern. Voidage times voidage factor is the voidage injection target.

wl List of injection wells for a pattern (see Section 1.5.2). Production from all layers will be used in the voidage calculation.

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nw Injection well number or well name.

lyrl List of layers to be used in the voidage calculation.

OFF Alpha label indicating that the pattern balancing option for the pattern will be turned off.

NOTE: If the WAG option is selected, two wells, one water injector and one gas injector, must be specified. Both wells must have the same layers for the voidage calculation. The calculated voidage target will be distributed to the WAG injectors according to the WAG ratio.If the WAG option is not selected and multiple injection wells are assigned to a pattern, the voidage calculation layers specified for each injector may not overlap. The parameter ratio may be set to zero, implying a gas injector only. But two wells must still be defined.

Example:

PATNCI 1 1.0 2PATNC I 2 0.8

3 1 -34 4 -6

PATNC I 3 OFFPATNCI 4 WAG 2.0 0.9 1 5

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3.12.3 Assign a Peripheral Production Well and Production Fractions to Multiple Patterns (PATNPP)

The PATNPP card is used to assign a peripheral production well to multiple patterns.

PATNPP nw EDGE

INNER ALL

LIQUID

pnl(prodf1 prodf2... prodfn)

Definitions:

nw Peripheral production well number or name.

EDGE Alpha label indicating that the producer is a boundary producer. The summation of the production fractions over all patterns for each boundary producer must be less than one.

INNER Alpha label indicating that the producer is an interior producer. This is the default. The production fractions for each interior producer must sum up to one over all patterns.

ALL Alpha label indicating that the pattern’s voidage is calculated using all three phases. This is the default.

LIQUID Alpha label indicating that the pattern’s voidage is calculated using liquid only.

pnl List of patterns to which a peripheral productor is being assigned (see Section 1.5.2).

prodf Production fractions for the production well being used in pattern’s voidage calculation. For an interior producer, default is the inverse of the number of patterns to which the well is assigned. For a boundary producer, production fractions must be specified.

NOTE: If specified, the number of prodf values must equal the number of patterns in the pattern list.The production fractions must be specified when the EDGE option is used.If the INNER option is selected and the production fractions for a production well are not specified, the default fraction for each pattern is

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the inverse of the number of patterns to which the well is assigned.

Example:

PATNPP 1 EDGE10.25

PATNPP 2 EDGE LIQUID1 22*0.25

PATNPP 3 INNER1 2 3 41 30.4 0.6

3.12.4 Same Perforations in Pattern Gas and Water Injectors (WAGPERF)

The WAGPERF card is used to insure that gas and water injectors in a pattern have the same perforations. If the perforations in only one injector are defined, the other injector will have the same perforations with the same properties. If the perforations in both wells do not match, the perforation data in one well (by default, the water well) is honored. The keyword GASWELL stipulates that the gas well perforations are to be honored instead.

WAGPERFOFF

ON GASWELL

Definitions:

OFF Alpha label indicating that the same perforation option is OFF. This is the default if the card is not entered.

ON Alpha label indicating that the same perforation option is ON, with the water injector being the honored one. This is the default when WAGPERF with no other parameters is entered.

GASWELL Alpha label indicating that the gas injector perforation data is honored, instead of the water injector.

3-188 5000.4.4


3.12.5 Voidage Calculation Based on GOR (PTNGOR)

The PTNGOR card is used to activate the option that voidage is to be computed using liquid phases only if the producer gas-oil ratio is greater than the user-specified value.

PTNGOR ptngor

Definition:

ptngor Gas-oil ratio, SCF/STB (SM3/STM3). If the producer gas-oil ratio is greater than ptngor, liquid voidage is to be used instead of total voidage. Default is to use total voidage.

3.12.6 Hydrocarbon Volumes and Angles (ATWGVA)

The ATWGVA card is used to assign the hydrocarbon pore volumes and angles for the wedges between a peripheral producer and pattern injectors. This card must be input if the automatic WAG option is invoked.

ATWGVA nwpnlPIVOL pivol1 pivol2 ... pivolnPIAGL piagl1 piagl2 ... piagln

Definitions:

nw Peripheral production well number or well name.

pnl List of patterns to which a peripheral producer is being assigned.

pivol Hydrocarbon volume for the wedge between the producer and the injector of each pattern on the specified pattern list, MSCF (SM3).

piagl Wedge angle open to flow at the injector of each pattern on the specified pattern list, radians.

NOTE: The number of pivol and piagl values must equal the number of patterns in the pattern list.

5000.4.4 3-189


Example:

ATWGVA 81 2PIVOL 3388000. 6776000.PIAGL 1.5708 1.5708

3.12.7 MI Injection Target and Allocation Parameters (ATWGCL)

The ATWGCL card is used to specify the total MI injection target for the automatic WAG option and some user-controlled category allocation control parameters.

ATWGCLMITAG mitarg(PCTFQ pctfq)(PCTMI nctmi)(PCTMN nctmn)

Definitions:

mitarg Total MI injection target for all automatic WAG patterns, MCSF/month (SM3/month).

pctfq Interval at which the allocation of pattern status will be recalculated, months. Minimum is 4 months.

nctmi Minimum number of allocation intervals a new pattern should be kept at Very Favorable status.

nctmn Minimum number of allocation intervals a pattern should be kept at the current status following a status change.

Example:

ATWCGLMITAG 96000.PCTFQ 12.PCTMI 3PCTMN 2

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3.12.8 Category Definitions and Injection Fractions (ATWGCT)

The ATWGCT card is used to specify fractions of the total throughput for each category and fraction of the total MI injection target allocated for each category.

ATWGCTpcttpf1 pcttpf2 pcttpf3pctmif1 pctmif2 pctmif3

Definitions:

pcttpfi Fractions of the total throughput for the Very Favorable, Normal, and Less Favorable categories, respectively. Sum of the three must not exceed 1.0.

pctmifi Fractions of the MI target allocated to the Very Favorable, Normal, and Less Favorable categories, respectively. Must sum up to 1.0.

Example:

ATWGCT0.2 0.5 0.20.4 0.5 0.1

NOTE: Each of the automatic WAG patterns is assigned as a Very Favorable (VF), Normal (N), Less Favorable (LF), or Suspended (S) category based on the pattern’s returned MI ratio. The VF group is defined as the best patterns (with lowest returned MI) whose combined throughput rates (reservoir liquid + gas) total pcttpf1 of the total throughput. This group is allocated pctmif1 of the targeted MI. A suspended pattern will not receive any MI allocation.

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3.13 Non-Darcy Gas Flow (Not available in VIP-THERM)

Two features modelling non-Darcy gas flow near wells are included in the well model: (1) pressure dependent density and viscosity, and (2) rate dependent well skin. These two features can be invoked separately.

A pressure dependent gas density and viscosity is specified by the WNDGDV card.

A rate dependent skin factor can be specified for a well using the WDNDG card or, for each perforation, using the FPERF card. When the rate dependent skin factor option is specified, the well index cannot be zero. A well index equal to zero is a special case which means adjusting the well index to honor both the rate and bottomhole pressure constraints. In such case, rate dependent skin factor does not have effective meanings. Thus, as error message will print in the output and the simulation run will be terminated.

3.13.1 Non-Darcy Gas Density and Viscosity Option (WNDGDV)

The WNDGDV card is used to specify the method for the calculation of pressure dependent gas density and viscosity for the well model.

WNDGDV

PP

RG

STD

(relerrndim)

Definitions:

PP Pseudo pressure option.

RG Russel Goodrich option.

STD Standard option. This is the default.

relerr Maximum relative error to be used in the integration of density to viscosity ratio for pseudo pressure option. Default maximum relative error is 0.01.

ndim Maximum number of intervals to be used in the integration is 2(ndim-1). The default ndim is 7; thus the default maximum number of intervals is 64.

NOTE: The pseudo pressure method uses an integration average between the gridblock pressure and the wellbore pressure adjusted to the gridblock depth to calculate density to viscosity ratio. The trapezoidal rule with Romberg’s extrapolation method is used for the integration.

3-192 5000.4.4


The Russell Goodrich method uses an average of the gridblock pressure and the wellbore pressure adjusted to the gridblock depth to calculate the injection and production gas density and viscosity.STD option uses the gridblock pressure to calculate the wellbore viscosity and density. The bottomhole pressure is not included in the calculation.Relerr and ndim are used only when the PP option is selected.

Example:

WNDGDV PP 0.005 8

3.13.2 Specify Rate-Dependent Skin Factors for Non-Darcy Gas Flow (WDNDG)

The WDNDG card is used to specify well rate dependent skin factors for non-Darcy gas flow.

WDNDG

INVK

INVKH

CON

wlwd1 wd2 ... wdn

Definitions:

INVK Inverse thickness option is used to allocate the well skin factor to its perforations. This is the default.

INVKH Inverse thickness-permeability option is used to allocate the well skin factor to its perforations.

CON Each perforation has the same rate dependent skin factor (the input wd value).

wl List of wells for which wd values are being entered (see Section 1.5.2).

wd Rate dependent skin factor, D/MSCF (D/SM3).

NOTE: The number of wd values must equal the number of wells in the well list.The perforation skin factors are calculated from the input well skin factor. When new perforation information is specified in the FPERF card, the program recalculates the skin factor for each perforation.

Example:

5000.4.4 3-193


WDNDG 1 -55*0.001

3.14 Automatic Recompletion Units

3.14.1 Recompletion Unit Status and Limit Data (RCMPPERF)

The RCMPPERF card is used to define the automatic recompletion units for wells. A TSTPRF card must be active for this option to be operational.

RCMPPERF SHUTIN

NOSHUTIN

WELL RCMPUNT(other headings)nw unit(other data)(Data cards are repeated as necessary to describe all the units for each applicable well.)

Definitions:

WELL Column heading for nw - the well number which must be entered for each data card. For multiple units in the single well the alpha label X can be substituted for the well number on each data card after the first.

RCMPUNT Column heading for unit - a recompletion unit for this well. Values must lie between 1 and the largest unit number specified for this well on the FPERF card.

SHUTIN Keyword indicating that if a well is about to be shutin for reasons such as minimum rate or no BHPTAB intersection, and if a unit with status AUTO is available, open that unit instead of shutting in the well.

NOSHUTIN Keyword indicating that, even if a unit with status AUTO is available, continue with the well shutin process. This is the default.

STATUS Column heading for status - the producing status of the performations in this unit. The possible values are:

OPEN Perforations are open to production (i.e., perforation status remains unchanged). This is the default.

AUTO Perforations are currently closed. The unit is eligible to be opened when an open unit is shut for limit violations.

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SHUT Perforations are closed. They can be opened only by subsequent RCMPPERF data.

OILMIN Column heading for oilmin - minimum total oil rate for a unit, STB/D (STM3/D). A violation causes the perforations in the unit to be closed and another unit (if available) to be opened. Default is 0.

GASMIN Column heading for gasmin - minimum total gas rate for a unit, MSCF/D (SM3/D). A violation causes the perforations in the unit to be closed and another unit (if available) to be opened. Default is 0.

GASMAX Column heading for gasmax - maximum total gas rate for a unit, MSCF/D (SM3/D). A violation causes the perforations in the unit to be closed and another unit (if available) to be opened. Default is 1.E20.

WTRMAX Column heading for wtrmax - maximum total water rate for a unit, STB/D (STM3/D). A violation causes the perforations in the unit to be closed and another unit (if available) to be opened. Default is 1.E20.

GORMAX Column heading for gormax - maximum total gas-oil ratio for a unit, SCF/STB (SM3/STM3). A violation causes the perforations in the unit to be closed and another unit (if available) to be opened. Default is 1.E20.

GLRMAX Column heading for glrmax - maximum total gas-liquid ratio for a unit, SCF/STB (SM3/STM3). A violation causes the perforations in the unit to be closed and another unit (if available) to be opened. Default is 1.E20.

LGRMAX Column heading for lgrmax - maximum total liquid-gas ratio for a unit, STB/MMSCF (STM3/KSM3). A violation causes the perforations in the unit to be closed and another unit (if available) to be opened. Default is 1.E20.

WCTMAX Column heading for wctmax - maximum total water-cut for a unit, fraction. A violation causes the perforations in the unit to be closed and another unit (if available) to be opened. Default is 1.

DPBHMX Column heading for dpbhmx - maximum drawdown constraint for a unit, psia (kPa). A violation causes the perforations in the unit to be closed and another unit (if available) to be opened. Default is to not check this constraint.

5000.4.4 3-195


TABLE Column heading for ibhptb - BHP table number to use for the well when this unit is opened. Default is to not change the table number.

STMMAX Column heading, in VIP-THERM only, for stmmax-maximum total steam rate for a unit, STB/D (STM3/D). A violation causes the perforations in the unit to be closed and another unit, if available, to be opened. Default is I.E.20.

SORMAX Column heading, in VIP-THERM only, for SORMAX-maximum total steam-oil ratio for a unit, STB(CWE)/STB (STM3(CWE)/STM3). A violation causes the perforations in the unit to be closed and another unit, if available, to be opened. Default is I.E.20.

NOTE: This data may only be specified if the dimension nrcmun is greater than zero.At least one of the other headings must appear on the title card along with the WELL and RCMPUNT headings.Any number of the other headings may be specified, up to and including all of them. For any unspecified status or limit, the previously input value or the default value will be used.The recompletion unit number must be less than or equal to the maximum unit number specified for the well on the FPERF card.

Example:

RCMPPERFWELL RCMPUNT WCTMAX STATUS

OILMIN1 1 0.95 OPEN

100.0X 2 0.90 AUTO

100.0X 3 0.95 AUTO

100.0X 4 0.95 AUTO

100.0X 5 0.99 AUTO

100.02 1 0.85 OPEN

100.0X 2 0.85 AUTO

100.0X 3 0.85 AUTO

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100.0X 4 0.85 AUTO

100.0

3.14.2 Order for Opening Recompletion Units (RCMPOR)

The RCMPOR card is used to define the order in which recompletion units should be considered for opening.

RCMPOR wliu1 iu2 ... iuk

Definitions:

wl List of wells to which this unit order list applies (see see Section 1.5.2).

iu Order in which the recompletion units should be considered for opening when a currently open unit is closed for a limit violation.

NOTE: This data may only be specified if the dimension nrcmun is greater than zero.A unit number may not be specified more than once in the list.The unit number must be less than or equal to the maximum unit number specified for the well on the FPERF card.An order list must be specified for a well if any units with status AUTO are to be opened.

Example:

RCMPOR 1 51 2 3 4 5

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3.15 WAG (Water-Alternating-Gas) Wells

3.15.1 WAG Injection Well Definition (WAG)

A WAG card must precede a QMAXWG card for WAG injectors.

WAG

STD

RES

FSTD

FRES GATHER

FLOSTA

AREA

FIELD

(KEYCMP)cwinjcginjncycle(GFIRST) GLAST SHUTIN

wl

( INITSLUGcwinji

X

cginji

X )

Definitions:




FSTD A fraction of the total surface production rate of the injected phase within a specified level of the well management hier-archy (see below).

FRES A fraction of the total fluid withdrawal (at reservoir condi-tions) within a specified level of the well management hier-archy (see below).

When FSTD or FRES is specified, the level in the well management hierarchy upon which replacement is based may be specified. The well management level may also be specified for MI injectors with STD or RES specification to identify the level upon which the MI composition determined from the MI plant in the major gas sales option is to be used for the injection composition. In this case, YINJ cards for MI injectors should be omitted and the MI plant calculation for the selected well management level must be invoked (see PLANT card in Section 4.5). The well management levels are:

GATHER Gathering Center. This is the default for FSTD or FRES specification.


AREA Area.

FIELD Field. This is the default for STD and RES specification with MI plant in the major gas sales option.

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If a gas conditioning plant in the major gas sales option is present, and keyword DIST is specified in the GASCOND card, a portion of the FSTD gas injectors may be assigned to receive the key component (component icomp in the GASCOND card) removed from the sales gas stream using the following keywords:

KEYCMP Alpha label indicating that the key component stream removed from the sales gas in the gas conditioning plant will be injected into the gas injectors specified in this WAG card. These gas injectors must be specified as FSTD injec-tors and a GASCOND card with keyword DIST must also be specified.

cwinj Cumulative water injection volume per cycle, in standard units, STB (STM3), if either STD or FSTD is specified; in reservoir units, rb, if either RES or FRES is specified. There is no default value.

cginj Cumulative gas injection volume per cycle, in standard units, MSCF (SM3), if either STD or FSTD is specified; in reservoir units, rb, if either RES or FRES is specified. There is no default value.

ncycle Total number of WAG cycles to be simulated. There is no default value.

GFIRST Alpha label indicating that the WAG cycling starts with gas injection. Default is water to be injected first.

GLAST Alpha label indicating that after the WAG cycling, injectors defined on this card will be switched to a gas injector. Default is the wells will be switched to a water injector.

SHUTIN Alpha label indicating that after the WAG cycling, injectors defined on this card will be shut-in. Default is the wells will be switched to a water injector.

wl List of all injection wells with rates specified in this manner (see Section 1.5.2).

INITSLUG Alpha label indicating that initial slug sizes are being entered. When this card is omitted, the cwinj and cginj from the WAG card are used for all slug sizes.

cwinji Initial water slug size, in standard units, STB (STM3), if either STD or FSTD is specified; in reservoir units, rb, if either RES or FRES is specified. Enter the alpha label X if this value should be the same as cwinj from the WAG card.

cginji Initial gas slug size, in standard units, MSCF (SM3), if either STD or FSTD is specified; in reservoir units, rb, if either RES or FRES is specified. Enter the alpha label X if this value should be the same as cginj from the WAG card.

NOTE: 1. Optionally, exactly one of the labels STD, RES, FSTD, and FRES

5000.4.4 3-199


may be specified. If none is specified, STD is the default.

2. Optionally, if either FSTD or FRES is specified, exactly one of the labels GATHER, FLOSTA, AREA, and FIELD may be specified. If none is specified, GATHER is the default.

3. Optionally, if either STD or RES is specified and the major gas sales option (with MI plants) for a well management level is invoked, the well management level (label GATHER, FLOSTA, AREA, or FIELD) may be specified to identify the level upon which the calculated MI composition from the MI plant is to be used as the injection composition. In this case, the injection composition (YINJ card) may be omitted (the input of YINJ card will cause the calculated MI composition to be ignored). If none is specified, FIELD is the default.

4. When a production well is converted to an injection well, any previously input WLIMIT, GLIMIT, or QMIN data will be ignored, and the ECOLIM unit will be set to the injection phase. Also, if the producer’s bhp value is the default value 0 psia, then the bhp value will be changed to 10,000 psia. Otherwise, previously input BHP or THP data will be maintained.

5. Anytime a WAG injection well is specified or respecified as either STD or RES, and the wells are not to be identified as MI wells (with MI plant in the major gas sales option), the composition of the injected gas must be defined using the YINJ card.

6. Optionally, if an FSTD WAG injection well is specified and a GASCOND card with keyword DIST is also present, keyword KEYCMP may be specified.

7. Specifying a WAG card for a shut-in well will cause the well to be “turned back on”.

8. For WAG injectors, values of cwinj, cginj, and ncycle must be specified. The simulator will automatically switch the wells between water injection and gas injection based on the user specified cumulative injection volumes per cycle (cwinj & cginj). The WAG cycling may either start with water injection (default) or gas injection (if GFIRST is specified). After ncycle cycles, the wells will be switched to regular water injectors (default), or regular gas injectors (if GLAST is specified), or shut-in wells (if SHUTIN is specified). For WAG injectors, QMAXWG cards must be used to specify both the maximum water injection rate and the gas injection rate (i.e., QMAX cards are omitted and replaced by QMAXWG cards). Optionally, a WAG well may have the same bhp and wdat values (using a standard BHP card) or different bhp and wdat values (using a BHPWAG card) or water and gas injection. The user may also specify the first timestep size after each changeover through a DTWAG card.

Example:

WAG FSTD FIELD 300000. 450000. 30 GFIRST SHUTIN 21 -30

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3.15.2 Maximum Rates for WAG Injectors (QMAXWG)

Must be preceded by a WAG card.

The QMAXWG card defines the maximum water and gas injection rates a WAG injector is allowed to inject.

QMAXWG wlqmaxw1 qmaxw2 ... qmaxwnqmaxg1 qmaxg2 ... qmaxgn

Definitions:

wl List of wells for which qmaxw and qmaxg values are being specified (see Section 1.5.2).

qmaxw Maximum water injection rate at which the WAG injector is allowed to inject. Units are determined by the WAG card. There is no default.

qmaxg Maximum gas injection rate at which the WAG injector is allowed to inject. Units are determined by the WAG card. There is no default.

NOTE: 1. During water injection, the WAG well injects at a rate of qmaxwunless this causes a violation of one of the other constraints defined by the user. Similarly, the WAG well injects at a rate of qmaxgduring gas injection unless this causes a violation of one of the other constraints defined by the user. In these events, the constraint is observed, which causes a rate reduction.

2. The number of qmaxw and qmaxg values must equal the number of wells in the well list.

3. For the FSTD injection option, qmaxw or qmaxg is the fraction of the total surface production rate of the injected phase within the appropriate level. For the FRES injection option, qmaxw or qmaxgis the fraction of the total reservoir volume production rate within the appropriate level.

4. For WAG injectors (WAG card), the QMAXWG card must be used and the QMAX card must be omitted.

Example:

CWAG STD 300000. 450000. 30 21 -30QMAXWG 21 -305*5000. 5*7000.5*12000. 5*15000.

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3.15.3 Bottomhole Pressure for WAG Injectors (BHPWAG)

To invoke BHPWAG constraints, the user must define a productivity/injectivity index (Section 3.6).

The BHPWAG card allows the user to define separate limiting bottomhole pressures during water and gas injection for WAG injectors.

BHPWAG wlbhpw1 bhpw2 ... bhpwnwdatw1 wdatw2 ... wdatwnbhpg1 bhpg2 ... bhpgnwdatg1 wdatg2 ... wdatgn

Definitions:

wl List of wells for which bhpw, wdatw, bhpg, and wdatg values are being entered (see Section 1.5.2).

bhpw Limiting bottomhole pressure for a WAG injector during water injection, psia (kPa); i.e., maximum allowed pressure for a WAG injector during water injection. Default is 10,000 psia.

wdatw Depth to which the limiting bottomhole pressure, bhpw, is referenced, ft (m).

bhpg Limiting bottomhole pressure for a WAG injector during gas injection, psia (kPa); i.e., maximum allowed pressure for a WAG injector during gas injection. Default is 10,000 psia.

wdatg Depth to which the limiting bottomhole pressure, bhpg, is referenced, ft (m).

NOTE: 1. The number of bhpw, wdatw, bhpg, and wdatg values must equal the number of wells in the well list.

2. For WAG injectors, BHP and/or WLWDAT cards may be entered instead of BHPWAG cards. If a BHP card is entered, the same bhp values will be used for water and gas injection. If a WLWDAT card is entered, the same wdat values will be used for water and gas injection.

Example:

C Specify bhp for WAG InjectorsBHPWAG 1 -150150*5000.150*8800.

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150*4500.150*8800.

3.15.4 Injection Temperature for WAG injectors (TINJWAG, VIP-THERM Only)

The TINJWAG card allows the user to define separate injection temperatures during water and gas injection for WAG injectors in VIP-THERM. Steam quality and injection pressure for water injection are specified with the QUAL and PINJ cards as for standard injectors.

TINJWAG wltinjw1 tinjw2 ... tinjwntinjg1 tinjg2 ... tinjgn

Definitions:

wl List of wells for which tinjw and tinjg are being specified (see Section 1.5.2).

tinjw Injection temperature for water injection, degrees F (degrees C).

tinjg Injection temperature for gas injection, degrees F (degrees C).

3.15.5 Timestep Controls for WAG Injectors (DTWAG)

The DTWAG card defines the maximum first timestep sizes following each changeover for WAG injectors specified in the WAG card.

DTWAG dtwtr dtgas

Definitions:

dtwtr The maximum first timestep size (days) following the changeover from gas injection to water injection for WAG injectors, days.

dtgas The maximum first timestep size (days) following the changeover from water injection to gas injection for WAG injectors, days.

Example:

DTWAG 1.5 1.0

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3.16 WBSIM (Gridded Wellbore) Well Definition (Not Available in VIP-THERM)

Horizontal flow into the wellbore (first vertical column of gridblocks) is calculated through normal Darcy radial flow equations, with the addition of an optional skin factor to adjust the transmissivity from gridblock 2 to gridblock 1 in the perforated layer. The keyword, COMPERF, is used to define the "perforations", which will then actually replace the reservoir transport terms for flow between gridblock 2 (reservoir) and gridblock 1 (wellbore) for the specified layers. The initial setup is to have no perforations at time zero. Perforations can be changed at any time in the simulator through the use of this keyword input. It is important to note that each set of COMPERF data are modifications to the perforations, and are not complete replacements. They may be entered any number of times throughout the simulator time.

3.16.1 WBSIM Well Perforations (COMPERF)

COMPERFcorrel (rough)(diam) (vcmult)(rdamp) (card 1)[K][H]

L [KH] (SKIN) (LEN) (ROUGH) (DIAM) (card 2)[K H]

[k][h]

l [kh] (skin) (len) (rough) (diam) (card 3)[k h]

[Repeat data card as necessary for subsequent perforations.]

Although the last four variables are optional, they are position dependent, such that if a variable is to be introduced, all of the variables before it must also be introduced.

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Definitions:

correl Name of the two-phase wellbore flow correlation to be used. This must always be specified. The options are:

NOSLIPNo phase slippage considered.

HAGEDOHagedorn and Brown

DUNROSDunns and Ross

BEGGSBeggs and Brill

AZIZAziz, Govier, Fogarasi

ORKISZOrkiszewski

GRIFFIGriffith, Lau, Hon, Pearson

rough Optional wellbore roughness, ft(m). If entered as -1., it will not be used. Otherwise, every interval [layer] in the wellbore will be set to this value.

diam Optional wellbore diameter, ft(m). If entered as -1., it will not be used. Otherwise, every interval [layer] in the wellbore will be set to this value.

vcmult Optional scale factor for the Turner minimum gas flow velocity necessary to lift liquid drops. Default value is 1.0.

rdamp Optional damping factor for phase migration at velocities below the minimum lift velocity. Default is 1.0. At upward flow velocities less than the minimum lift velocity, the mixture density gradient is replaced by the following damped liquid and vapor phase gradients in the respective phase potentials.

ml m l m– vc v–

vc rdamp 1– v+------------------------------------------------- +=

mg m g m– vc v–

vc rdamp 1– v+------------------------------------------------- +=

Immediately following the COMPERF data entry line there must be another line of keywords defining the types of data that will be entered next in redefining the wellbore ’perforations’.

5000.4.4 3-205


Definitions:

L Column heading for l, the layer number for which this perforation data applies.

K Column heading for k, the permeability of this perforation, md.

H Column heading for h, the thickness of this perforation, ft(m).

KH Column heading for kh, the permeability-thickness product of this perforation, md-ft(md-m).

SKIN Column heading for skin, the skin factor for this perforation.

LEN Column heading for len, the actual wellbore length within this layer, ft(m).

ROUGH Column heading for rough, the wellbore roughness, ft(m).

DIAM Column heading for diam, the wellbore diameter within this layer, ft(m).

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3.16.2 Dynamic Vertical Flow Transport Parameters Calculation

All vertical flow transport parameters for the first column of gridblocks (wellbore) are calculated dynamically for each timestep, with special treatment for the phase mobilities. These calculations are as follows :

n Phase mobilities for flow in the wellbore are based on the mixture viscosity, instead of the phase viscosity.

n If the gas flow velocity is greater than the minimum gas lift velocity, the gravity gradients in the wellbore are based on the mixture density, instead of the individual phase densities. If the gas flow velocity is less than the minimum gas lift velocity, the damped phase gradients are used instead of the individual phase gradients.

n The pressure drop in the wellbore can be described as the sum of the pressure drops due to friction, gravity, and kinetic energy. The kinetic energy pressure loss is usually quite small and is neglected. At the start of each timestep, the gas and liquid superficial velocities are calculated based on the converged conditions at the end of the previous timestep. From this, the Reynold’s number and friction factor are calculated for each segment from the specified correlation, after which the average mixture velocity and then the equivalent Darcy velocity are calculated. The effective wellbore vertical permeability (Kwe) is then calculated, and held constant over the timestep.

n Phase "relative permeabilities" in the wellbore are set equal to the phase saturations, with the exception that krg = * Sg, where is slippage factor greater than or equal to 1.0, which allows the gas phase to flow at an equal or greater velocity than the liquid phase. The slippage is obtained from the specified correlation.

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3.17 Automatic Cycle Control (VIP-THERM)

NOTE: Note: An AUTOCYCLE card must be entered in the utility data to use this option.

This option is designed to dramatically reduce the user effort required to make predictive runs for cyclic steam operations,when the schedules of the well cycles are controlled by measurable conditions. However,it is implemented in general such that any process involving wells alternating between injection and production can be automatically controlled.

Wells are automatically switched between injection and production based on a user-selected set of available constraints. Each cycle consists of an injection, a soak, and a production phase. The order of the cycle phases may be specified, i.e. cycles may be defined as injection/soak/production or as production/injection/soak. The latter allows automatic control of the length of a primary production period, since all switching and well constraints may be specified by cycle.

A VIP-EXEC Autocycle report is automatically written to the output file on each status change (start, stop, phase switching, abort,etc.) for each cyclic well, which gives well status, action taken, and the reason for the action taken. For output purposes, the time at the end of any cyclic wells' injection or production phase (tcpe, which is computed as described in the following sections) is treated as if a TIME/DATE card were entered at tcpe. For example, a PRINT WELLS TIME card will result in well summaries printed to the output file at the end of each injection or production phase for any cyclic well. A PRINT WELLS TNEXT card will apply only at the first subsequent time at which a cyclic wells' injection or production phase ends, or at the next input TIME/DATE card, whichever occurs first.

Required data (CYCLETABLE, CYCLIC and CSTART) and optional data (CSTOP and CPERF) are described in the following sections.

3.17.1 Cycle Tables (CYCLETABLE)

Each cycle table is assigned a cycle table number. Wells are defined as cyclic and assigned to cycle table numbers with the CYCLIC card as defined in the next section.

The cycle table specifies the well types of the injector (CINJ card and producer (CPROD card), the constraints to be used for switching from injection to (soak/) production (ITOP card), the constraints to be used for switching from production to injection (PTOI card), and the values of the switching constraints and well constraints (CYCLE data). Optionally, constraints for aborting cyclic injection/production may be entered (ABORT card), which if violated result in shutting the well in.

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CYCLETABLE (PFIRST) ictCINJ W STD GATHER

G RES FLOSTAFSTDAREAFRES FIELD

CPROD W STDO RESG MOLESALLLIQUID

ITOP A IPLABEL1 A IPLABEL2 ... A IPLABELnip O O OPTOI A PILABEL1 A PILABEL2 ... A PILABELnip O O O(ABORT ALABEL1 ALABEL2 ... ALABELna)CYCLE DTSOAK QMAXI BHPI DEPI (TINJ) (QUAL) (PINJ) QMAXP BHPP DEPP SLABELS

1 dtsoak qmaxi bhpi depi (tinj) (qual) (pinj) qmaxp bhpp depp sl(ns)

( 2 dtsoak qmaxi bhpi depi (tinj) (qual) (pinj) qmaxp bhpp depp sl(ns) )

( . . . . . . . . . . . . )

( . . . . . . . . . . . . )

(ncyc dtsoak qmaxi bhpi depi (tinj) (qual) (pinj) qmaxp bhpp depp sl(ns) )

Definitions: (the constraint values in the CYCLE data, shown in lower case, are defined along with their corresponding alpha labels)

PFIRST Alpha label indicating that the cycle phase order is injection/soak. The default order is injection/soak/production.

ict Cycle table number.

CINJ card Alpha labels specifying the injector well type for the cyclic well(s) assigned to this table. See Section 3.4.2 (INJ card) for label definitions.

CPROD card Alpha labels specifying the producer well type for the cyclic well(s) assigned to this table. See Section 3.4.1 (PROD card) for label definitions.

ITOP Alpha label indicating that the following alpha labelsdefine the constraints to be used for switching frominjection to (soak/)production. The subscriptsshown in the format do not appear in the data deck.

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A, O Each switching constraint label on the ITOP card must be preceded by an A or an O. A indicates 'and', and O indicates 'or'. Switching will occur if all of the 'and' constraints are violated or if any of the 'or' constraints are violated.

nip The number of ITOP constraints specified. May be any number greater than zero and less than or equal to 4.

IPLABELn Any of the following alpha labels, for n equals 1 to nip, defining constraints to be used for switching from injection to (soak/)production; Switch if (and/or):

QMINI Injection rate is less than or equal to qmini, STB/D (STM3/D) for water injectors or MSCF/D (SM3 D) for gas injectors.

CMAX Cumulative injection is greater than or equal to cmax, MSTB (KSTM3) for water injectors or MMSCF (KSM3) for gas injectors.

DTMINI Injection phase length is greater than or equal to dtmini, Days.

DTMAXI Injection phase length is equal to dtmaxi, Days.

PTOI Alpha label indicating that the following alpha labels define the constraints to be used for switching from production to injection. The subscripts shown in the format do not appear in the data deck.

A, O Each switching constraint label on the PTOI card must be preceded by an A or an O. A indicates 'and', and O indicates 'or'. Switching will occur if all of the 'and' constraints are violated or if any of the 'or' constraints are violated.

npi The number of PTOI constraints specified. May be any number greater than zero and less than or equal to 8.

PILABELn Any of the following alpha labels, for n equals 1 to npi, defining constraints to be used for switching from production to injection; Switch if (and/or):

QOMIN Oil production rate is less than or equal to qomin, STB/D (STM3/D).

QGMIN Gas production rate is less than or equal to qgmin, MSCF/D (SM3/D).

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WCMAX Water cut is greater than or equal to wcmax, fraction. Note that the water cut includes all produced steam in VIP-THERM.

OIRMAX Ratio of cumulative produced oil in production phase to cumulative injection in previous injection phase is greater than or equal to oirmax, MSTB/MSTB CWE (KSTM3/KSTM3 CWE) for CINJ W or MSTB/MMSCF (KSTM3/KSM3) for CINJ G.

GIRMAX Ratio of cumulative produced gas in production phase to cumulative injection in previous injection phase is greater than or equal to girmax, MMSCF/MSTB CWE (KSM3/KSTM3 CWE) for CINJ W or MMSCF/MMSCF (KSM3/KSM3) for CINJ G.

TMIN Average wellblock temperature is less than or equal to tmin, degrees F (degrees C). Allowed in VIP-THERM only

DTMINP Production phase length is greater than or equal to dtmini, Days.

DTMAXP Production phase length is equal to dtmaxi, Days.

na Number of abort constraint labels specified on the ABORT card.

ABORT Alpha label indicating that the na alpha labels which follow define the constraints to be used for aborting the cycles, shutting the well in. All abort constraints except for DTMXPA are checked at the end of each each production phase.

ALABELn Any of the following alpha labels, for n equals 1 to na:

DTMXPA Abort if production phase length is greater than or equal to dtmxpa.

QOAPMN Abort if average oil production rate over the last set of injection/soak/production phases is less than or equal to qoapmn, STB/D (STM3/D).

QGAPMN Abort if average gas production rate over the last set of injection/soak/production phases is less than or equal to qgapmn, MSCF/D (SM3/D).

WCAVMX Abort if average water cut in the production phase (cumulative water produced / cumulative water produced + cumulative oil produced) is greater than or equal to wcavmx, STB/STB (STM3/STM3).

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OIRMIN Abort if ratio of cumulative oil produced in production phase to cumulative injection in previous injection phase is less than or equal to oirmin, STB/STB (STM3/STM3) for CINJ W or STB/MSCF (STM3/SM3) for CINJ G. This is referred to as the oil-steam ratio (OSR) in cyclic steam operations.

GIRMIN Abort if ratio of cumulative gas produced in production phase to cumulative injection in previous injection phase is less than or equal to girmin, MMSCF/MSTB (KSM3/KSTM3) for CINJ W or STB/MSCF (KSM3/KSM3) for CINJ G.

ns The total number of constraint labels specified on ITOP, PTOI, and ABORT cards, ns = nip + npi + na.

CYCLE First alpha label on column header card containing alpha labels for all required well constraints and containing the set of all ns alpha labels for constraints specified on ITOP, PTOI, and ABORT cards (SLABELS).

DTSOAK Column header for length of soak phase dtsoak, Days. Required.

QMAXI Column header for maximum injection rate qmaxi. Units are determined by the CINJ card.Required.

BHPI Column header for maximum bottomhole pressure during injection bhpi, psia (kPa). Required.

DEPI Column header for reference depth corresponding to bhpi, depi, ft (m). Required.

TINJ Column header for injection temperature tinj, degrees F (degrees C). Required in VIP-THERM, not allowed otherwise.

QUAL Column header for injected steam quality qual, mass fraction steam. Required in VIP-THERM with CINJ W, not allowed otherwise.

PINJ Column header for injected steam pressure pinj, psia (kPa). Required in VIP-THERM with CINJ W when any cycle value for qual is equal to zero or one, not allowed otherwise.

QMAXP Column header for maximum production rate. Units are determined by the CPROD card. Required.

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BHPP Column header for maximum bottomhole pressure during production bhpp, psia (kPa). Required.

DEPP Column header for reference depth corresponding to bhpp, depp, ft (m). Required.

ncyc The number of cycles for which data are specified. If equal to one, then the data are constant for all cycles. If greater than one, then NCYCMX must be specified on the DIM card.

sl(ns) The values of the ns switching constraints, defined above with their corresponding alpha labels.

NOTE: 1. Any number (greater than zero) of ITOP, PTOI, and ABORT constraint labels may be entered in any order. Columns may be defined on the CYCLE card in any order. 2. The program is dimensioned for a maximum of 10 cycle tables and for a maximum of 1 cycle entry per cyclic table (ncyc = 1). These dimensions may be changed through specification of NCYCTM and NCYCMX on the DIM card.3. Timestep size will be modified in order to exactly satisfy the DTSOAK, O DTMINI, O DTMAXI, O DTMINP, and O DTMAXP switching constraints. It is also modified to exactly satisfy the 'A' DT constraints if all of the other 'A' constraints are satisfied at the time the timestep size is computed. Timestep size is not altered to attempt to satisfy any of the other switching constraints exactly; they are simply checked for violation at the beginning of each timestep. Therefore, the maximum timestep size should not be greater than the maximum allowable error in the predicted lengths of the cycle phases, unless the phase lengths are controlled only by time constraints. 4. Other well constraints not included in the cycle table and described in Section 3.5, for example WLIMIT, GLIMIT, PRFLIM, YINJ, QSTMX, and GORPEN, may also be entered as desired or required (YINJ is required for cyclic gas injectors), and they apply to the appropriate cycle phase.5. Options for treatment of production and injection wells described in Section 3.4, such as WINJMOB, GINJMOB, ITNSTP, ITNSTQ, and ITNGRE may be entered as desired and apply to the appropriate cycle phase.6. Cycling of any well will be automatically aborted for any well in which the cumulative injection in an injection phase, or the cumulative oil and gas production in a production phase, is zero.7. If all defined wells are cyclic, then the run will be automatically

5000.4.4 3-213


terminated after the cycling of all wells have either finished (completed the specified maximum number of cycles in the CYCLIC data), been aborted, or been stopped (CSTOP card).

3.17.2 Cyclic Well Definition (CYCLIC)

Cyclic wells are defined with the CYCLIC card analogously to definitions of other well types with the PROD, INJ, or WAG cards. Their locations and perforations are defined as for all wells by WELL and FPERF cards. Subsets of the total number of perforations defined on the FPERF card may be defined as open to injection or open to production using the CPERF card as described in the next section.

Wells specified on the CYCLE card are assigned to cycle tables and are assigned a maximum number of cycles to complete.

CYCLIC wlict1 ict2 ... ictn ncyc1 ncyc2 ... ncycn

Definitions:

wl List of wells for which values are being specified (see Section 1.5.2).

ict Cycle table number.

ncyc Maximum number of cycles to perform.

NOTE: 1. QMAX, QMIN, ECOLIM, BHP, TINJ, QUAL, and PINJ cards should be omitted for cyclic wells. These constraints are represented in the cycle table.2. Wells completing the specified maximum number of cycles are shut in.3. The cycle table must be defined before a well is assigned to it.

3.17.3 Cycle Phase Perforation Status (CPERF)

NOTE: FPERF and CYCLIC data must precede CPERF data.

All perforations open to either injection or production are specified on the FPERF card. The CPERF card may optionally be used to define the subset of total perforations open to injection and to production, either statically or by cycle number. If the number of cycles for which data is specified, ncyc, is equal to one,

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then the data are constant for all cycles. All wells in the well list on a single CPERF card must contain the same number of perforations. A single set of perforation status values are specified which apply to all wells in the well list.

CPERF wl 1 i1 i2 ... inp X p1 p2 ... pnp( 2 i1 i2 ... inp )( X p1 p2 ... pnp )( . )( . )( ncyc i1 i2 ... inp )( X p1 p2 ... pnp )

Definitions:

wl List of wells for which values are being specified (see Section 1.5.2).

np The number of perforations per well.

ncyc The number of cycles for which dataare specified. If equal to 1, then the data are constant for all cycles. If greater than one, then NCYCMX must be specified on the DIM card.

X Alpha label indicating productionperforation status values follow for the cycle number defined on the previous card.

i1 i2 .. inp Status for each of the np perforationsfor the cycle injection phase in order of their definition on the FPERF card. A value of 0 indicates closed, a value of 1 indicates open.

p1 p2 .. pnp Status for each of the np perforations for the cycle production phase in order of their definition on the FPERF card. A value of 0 indicates closed, a value of 1 indicates open.

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NOTE: 1. The program is dimensioned by default for a maximum value of ncyc of 1. This value may be changed with the NCYCMX parameter on the DIM card.2. If it is desired to change any of the FPERF data by cycle phase for perforations which are open to both injection and production, then two perforations should be defined in the same location in the FPERF data, with injection properties assigned to one and production properties assigned to the other. The CPERF card can then be used to inject with injection perforation values and to produce with production perforation values.3. If a well using the CPERF option is reperforated with an FPERF card, the status values are all reset to open. CPERF data may be re-entered after the FPERF data.

3.17.4 Start Cycle (CSTART)

The CSTART card must follow all CYCLETABLE and CYCLIC data and initiates the cycles by well or for all cyclic wells in the specified well management levels. Optionally, cycling in the wells or well management levels may be specified as starting after completion of all cycling in another well or well management level.

CSTART WELL inumGATHERFLOSTAAREA FIELD

(AFTER inuma)

Definitions:

inum List of well or well management level names or numbers to start cycling. The rules for inum are the same as for well lists (see Section 1.5.2).

AFTER, inuma Optional alpha label indicating that the start of cycling for each well or for each well in the well management level in the inum list follows completion of all cycling in the corresponding well or well management level in the inuma list.

NOTE: 1. AFTER cannot be used with CSTART FIELD.2. The inum value is arbitrary for CSTART FIELD; it may be omitted. 3. A wells' cycling is completed when it has performed the maximum specified number of cycles, when is has been aborted, or when it has been

3-216 5000.4.4


stopped (CSTOP). 4. Specification of multiple CSTART cards which apply to the same well will result in a warning message being written to the output file, unless they are separated by a new CYCLIC specification for the well (see note 5 below). The first input CSTART card (after the CYCLIC card) which applies to a given well will be honored. 5. Any cyclic well may be restarted, beginning with cycle number 1, by re-entering CYCLIC and CSTART cards for the well. Any pre-existing CPERF data for the well will be retained.

3.17.5 Stop Cycle (CSTOP)

The CSTOP card may appear anywhere in the recurrent data after the corresponding CSTART card and terminates the cycle(s) for the specified well(s) or for all wells in the specified well management level.

CSTOP WELL inumGATHERFLOSTAAREAFIELD

Definitions:

inum List of well or well management level names or numbers to stop cycling. The rules for inum are the same as for well lists (see Section 1.5.2)

NOTE: 1. The first CSTOP card input which applies to a given well is honored. Subsequent CSTOP cards applying to that well are ignored.2. Specifying a CSTOP card for a well which has not been started by a CSTART card, or which has not started to cycle due to AFTER constraints, will override the CSTART/AFTER cards, and will result in a warning message being written to the output file.3. A cyclic well that is stopped by a CSTOP card can be restarted by subsequent input of CYCLIC and CSTART cards for the well. The cycle number is reset to 1 in this case.

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3.18 Condensate Banking

In gas condensate reservoirs, a liquid phase appears near the wellbore when the pressure in this region drops below the dewpoint. Initially, the liquid is immobile. Gas relative permeability is also decreased. The degree of decrease depends on the saturation of the liquid phase and the shape of the gas relative permeability curve. In a normal coarse grid system, the decline in gas productivity is underestimated because the gas saturation used for well productivity calculations is that of the entire gridblock. Condensate banking more closely approximates the loss of gas productivity by integrating mobility from the bottomhole flowing pressure to the gridblock pressure. Gas saturation can be related to the pressure by certain simple assumptions.

To use condensate banking, both the CNDBNK and CNDBWL keywords must be specified.

When velocity dependency is applied to wells, the condensate banking option is automatically activated for every production well. The parameters on the condensate banking control cards are ignored, except for the number of intervals to be used for the numerical integration. By default, four intervals are used in each phase region. Condensate banking can be used with or without velocity effects. 00

3.18.1 Condensate Banking Calculation Parameters (CNDBNK)

The CNDBNK card is used to turn on the condensate banking option and to adjust the numerical integration parameters. Usually, it is sufficient to just use the CNDBNK keyword without any additional parameters, which indicates that a trapezoid rule with four intervals will be used for the integration.

CNDBNK TRAP nintROM ndim eps

Definitions:

TRAP Numerical integration is performed using the trapezoidal integration method. If the CNDBNK keyword is entered with no other parameters, this is the default method used.

nint Number of integration intervals used for the trapezoidal method. The default number of intervals is 4.

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ROM Numerical integration is performed using the Romberg method, which sets the number of integration intervals depending on the maximum relative error specified by eps.

ndim The maximum number of integration intervals used by the Romberg method is calculated as 2**(ndim-1). The actual number of intervals used may be less than this number, but it cannot exceed it. By default, ndim is set to 7, which in turn sets the maximum number of intervals to 64.

eps The maximum relative error used to determine the number of integration intervals appropriate for Romberg integration. By default, eps is set to 0.01. The ndim parameter must precede eps.

Example:

C Use default condensate banking integration parameters CNDBNK

3.18.2 Selective Application of Condensate Banking (CNDBWL)

Condensate banking may be selectively turned on for a list of wells. It may also be applied to all wells within a gathering center, a flow station, an area, or the field. Condensate banking will not be automatically used for any well by use of just the CNDBNK keyword.

Whether condensate banking is applied to a well is determined by the CNDBWL data specified at the lowest level of the well hierachy, which is in the following order:

1. the well

2. the appropriate gathering center

3. the appropriate flow station

4. the appropriate area

5. the field.

To selectively apply condensate banking to particular wells, the CNDBWL keyword is used in the following form:

CNDBWL WELL ON

OFFwl

5000.4.4 3-219


Definitions:

WELL Indicates that condensate banking will be selectively turned on or off for the wells in the following list.

ON Indicates condensate banking will be applied.

OFF Indicates condensate banking will not be applied.

wl List of wells for which the condensate banking data applies (see Section 1.5.2).

To selectively apply condensate banking to all the wells in a particular well group hierarchy, the CNDBWL keyword is used in the following form:

CNDBWL

GATHERFLOSTAAREAFIELD

inum ONOFF

Definitions:

GATHER Turn condensate banking on or off for the specified gathering center.

FLOSTA Turn condensate banking on or off for the specified flow station.

AREA Turn condensate banking on or off for the specified area.

FIELD Turn condensate banking on or off for the field.

inum Number of the member in the specified well management level.

ON Turn condensate banking on for the specified well group.

OFF Turn condensate banking off for the specified well group.

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3.19 Well Index Multipliers

The well index multiplier option allows the user to simulate the effect of phenomena such as water scaling on the well index of producing wells. The computed multiplier is determined from a table of multipliers as a function of historical maximum water cut, cumulative reservoir total production, or cumulative reservoir water production.

3.19.1 Assignment of WI Multiplier Tables (WIMUWL)

WIMUWL wlitab1 itab2...itabn

Definitions:

wl List of wells for which tables are being assigned (see Section 1.5.2).

itab Number of the WI multiplier table for this well. Default is 0.

NOTE: The number of itab values must equal the number of wells in the well list.A value of 0 for itab denotes that the multiplier option is disabled for the well.When the corresponding itab table uses one of the cumulative reservoir production options, setting itab for the well forces the algorithm to do the table lookup for the well as a whole. A subsequent FPERF card for this well with iwim entered will switch to table lookup for each perforation.

3.19.2 WI Multiplier Tables (WIMULTAB)

WIMULTAB itab

WCUT

RESTOT

RESWATWIMULT

val1 wimult1 . . . . . .valn wimultn

Definitions:

5000.4.4 3-221


itab Number of the WI multiplier table being read.

WCUT Alpha label indicating that this column contains water-cut data. The order of the WCUT and WIMULT columns may be reversed.

RESTOT Alpha label indicating that this column contains cumulative reservoir total production data. The order of the RESTOT and WIMULT columns may be reversed.

RESWAT Alpha label indicating that this column contains cumulative reservoir water production data. The order of the RESWAT and WIMULT columns may be reversed.

WIMULT Alpha label indicating that this column contains WI multipliers. The order of the WCUT and WIMULT columns may be reversed.

val For WCUT, historical maximum water cut, fraction. For RESTOT, cumulative reservoir total production, mrb (krm3). For RESWAT, cumulative reservoir water production, mrb (krm3). Values must increase monotonically and may be unequally spaced.

wimult WI multipliers.

3.19.3 Outer Iteration Number (ITNWIMULT)

The ITNWIMULT card is used to set the outer iteration number after which the WI multiplier will not be updated.

This data applies only to the WI multiplier tables with the WCUT option.

ITNWIMULT itnwim

Definition:

itnwim Outer iteration number. Default is 1 and the maximum value is 3.

NOTE: In order to insure good material balance, if itnwim is greater than 1, the itnmin value on the ITNLIM card must be greater than itnwim.

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3.19.4 Reset Cumulative Reservoir Production (RESETCUM)

By default, well and perforation cumulative reservoir production (for the WI multiplier table option only) is computed from the time a well starts producing. The RESETCUM card allows the user to force these cumulatives to be reset to zero at the time the data is entered.

RESETCUM wl

Definitions:

wl List of wells for which the well and perforation cumulative reservoir production values are reset to zero (see Section 1.5.2).

Example:

DIM NWIMMX NWIMV 2 6

WIMULTAB 1WCUT WIMULT0.0 1.00.2 0.80.5 0.50.8 0.31.0 0.1

WIMULTAB 2WCUT WIMULT0.0 1.00.1 0.80.3 0.50.6 0.30.7 0.21.0 0.01

WIMUWL A-01 A-02 2 1

ITNWIMULT 1

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3-224 5000.4.4

Chapter

4

00000Well Management Level Data

4.1 Introduction

00 Reporting of production/injection results and various production/injection constraints may be given at the gathering center, flow station, area, and/or field levels. (Only one field exists in the model. All areas are attached to the field.) The following data cards set up the hierarchy among the levels.

4.2 Well Management Levels

4.2.1 Well Management Level Definition (GATHER, FLOSTA, AREA)

GATHER igc (gcname) fsnum (card 1)FLOSTA ifs (fsname) areanm (card 2)AREA iar arname (card 3)

00 Definitions:

GATHER Alpha label indicating a gathering center is being defined.

igc Gathering center number.

gcname Gathering center name. The first character in the name must be alphabetic unless the name is immediately preceded by the character #. Only the first eight (8) characters of the name are retained. Default is blanks.

fsnum Flow station number to which this gathering center belongs. Default is 1.

FLOSTA Alpha label indicating a flow station is being defined.

ifs Flow station number.

fsname Flow station name. The first character in the name must be alphabetic unless the name is immediately preceded by the character #. Only the first eight (8) characters of the name are retained. Default is blanks.

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areanm Area number to which this flow station belongs.Default is 1.

AREA Alpha label indicating an area is being defined.

iar Area number.

arname Area name. The first character in the name must be alphabetic unless the name is immediately preceded by the character #. Only the first eight (8) characters of the name are retained. Default is blanks.

4.2.2 Fraction of Time Management Level is Onstream (ONTIME)

00 Ontime factors do not apply to injection wells using either of the FSTD or FRES reinjection options.

00 The ONTIME card is used to specify the fraction of the time that a well is actually producing/injecting. The fraction is applied to the well rate after the rate has been determined by QMAX or pressure constraints and after the well minimum rate (QMIN), water cut (WLIMIT), and GOR (GLIMIT) checks.

00 Ontime factors may be input at the well level or at any other level of well management. The effective ontime factor for a well will be the one specified at the lowest level of the well hierachy; that is, the first user-specified factor found in this order:

1. the well,

2. the appropriate gathering center,

3. the appropriate flow station,

4. the appropriate area,

5. the field.

ONTIME

GATHER

FLOSTA

AREA

FIELD

inum

ALL

PROD

INJ

ontime MULTALLWELLS

00 Definitions:

Alpha label indicating the level of the well management hierarchy to which the specified ontime factor applies:

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GATHER Gathering center.


AREA Area.

FIELD Field.


Alpha label indicating that the ontime value applies to:

ALL All the wells. This is the default.

PROD Producing wells only.

INJ Injecting wells only.

ontime Fraction of the time that each well is actually producing/injecting. Default is 1.0.

MULT Alpha label indicating that the ontime factor specified on this card will be a multiplier to any previously specified ontime factor at the AREA level or below. The value on this card will apply if no ontime factors have previously been specified. This may only be input if FIELD was entered.

ALLWELLS Alpha label indicating that the ontime factor applies to all wells of the appropriate type (ALL, PROD, or INJ) in the field, superceding any previously entered factor. This may only be input if FIELD was entered.

NOTE: 1. One and only one of the GATHER, FLOSTA, AREA, or FIELD labels must be specified. There is no default. When FIELD is specified the inum entry may be omitted or the value 1 may be input; no other value will be accepted.

2. One and only one of the ALL, PROD, or INJ labels may be specified. If none is specified, ALL is assumed.

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4.3 Production and Injection Targeting

4.3.1 Production Target (PTARG)

00 A PTARG card is used to define a maximum production rate for a gathering center, a flow station, an area, or the field.

PTARG

GATHER

FLOSTA

AREA

FIELD

inum

O

W

G

L

qtargLFTGAS

NOLFTGAS

00 Definitions:

Alpha label indicating the level of the well management hierarchy to which the specified maximum production rate applies:



AREA Area.

FIELD Field.


Alpha label indicating the maximum rate is based on:

O Oil production, STB/D (STM3/D).

W Water production, STB/D (STM3/D).

G Gas production, MSCF/D (SM3/D).

L Liquid production, STB/D (STM3/D).

qtarg Maximum production rate.

LFTGAS Alpha label indicating that the gas production target qtarg also includes the amount of gaslift gas used in the specified level of well management. This option applies only when the label G is specified.

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NOLFTGAS Alpha label indicating that the gas production target qtarg does not include gaslift gas. This is the default. This option applies only when the label G is specified.

00 Notes:

1. For predictive well management, a different format of PTARG card should be used. Refer to Chapter 5 of this manual.

2. One and only one of the GATHER, FLOSTA, AREA, or FIELD labels must be specified. There is no default. When FIELD is specified the inum entry may be omitted, or the value 1 may be input; no other value will be accepted.

3. One and only one of the O, W, G or L labels must be specified. There is no default. Separate maxima can be established for oil, water, gas, and liquid by reading multiple PTARG cards.

4. The oil, water, gas and liquid maxima may be exceeded by the tolerance factors specified on the TRGTOL card before violations occur.

5. The maximum rate criteria are satisfied first at the gathering center level, then the flow station level, then the area level, and finally at the field level. The order in which phase targets are checked at any well management level is determined by the data specified using the TRGORD card. If the TRGORD card is not specified, the default order is: oil, gas, liquid, water.

6. The method used to satisfy the maxima may be specified on the TRGOPT card.

7. The LSCALE card may be used to specify how well rates should be recomputed when reductions are necessary. The choices are linear scaling or rigorous recomputation.

8. Wells whose rates have been reduced due to targeting are designated by TARG in the production well summary.

9. Well rates will never be reduced below trgqmn, except possibly by the AVG method.

10. The labels LFTGAS and NOLFTGAS apply only when the label G is specified.

00 Example:

00 PTARG FIELD 1 O 150000PTARG GATHER 2 L 50000PTARG AREA 1 G 10000 LFTGAS

5000.4.4 4-229


4.3.2 Production Target History Option (PTARGH)

00 A PTARGH card is used to activate the option that production targets are honored, even if well production rates must be increased above their specified maxima.

PTARGH

ON

OFF

00 Definitions:

ON Alpha label indicating that the production target history option is to be used.

OFF Alpha label indicating that the production target history option is not to be used. This is the default.

NOTE: 1. When the PTARGH option is on and a production rate in a member of a well management level falls below its user-specified production target (PTARG), a scaling algorithm is used to increase the rates in appropriate wells. An appropriate well is a well in the affected member of well management whose production rate is at the specified well maximum (QMAX).

2. Only one pass through the appropriate wells is undertaken. If a well cannot produce at its new increased rate, it will produce what it can and the target will not be reached.

3. When the PTARGH option is on, the LSCALE option must be off; i.e., the perforation rates will be recalculated, not scaled. OFF is the default value for LSCALE.

4-230 5000.4.4


4.3.3 Production Target Frequency (PTGFRQ)

00 The PTGFRQ card is used to control the frequency with which the ordered lists of wells (i.e., GOR, WCUT) used in production targeting are created.

PTGFRQ freq

MONTHS

DAYS

TSTEPS

00 Definitions:

freq Frequency with which the ordered lists of wells used in the production targeting calculations will be created. Default is every timestep.

MONTHS Alpha label that sets the unit for freq to months.

DAYS Alpha label that sets the unit for freq to days.

TSTEPS Alpha label that sets the unit for freq to timesteps.

NOTE: 1. When the TEST card frequency for attempting to reopen one or more shut-in wells causes the test to occur when the targeting is being delayed by the PTGFRQ data, the test will be deferred until the next time the full targeting algorithm is performed.

2. Within the simulator the date on a DATE card is considered to be the beginning of that day. For example, if output is desired at the end of March 1988, the date card should contain 1/4/88 and not 31/3/88. Thus the MONTHS option on the frequency card will force a timestep to start at the date 1/month/year.

5000.4.4 4-231


4.3.4 Options for Reduction of Rates to Meet Target (TRGOPT)

00 A TRGOPT card is used in conjunction with the PTARG card to define the method of reducing the phase rate of wells to meet the specified phase targets.

TRGOPT

GATHER

FLOSTA

AREA

FIELD

inum

O

G

W

L

SCALE

AVG

GOR

WCUT

WRATE

GRATE

AVGGOR

AVGWOR

AVGLOR

AVGWCT

00 Definitions:

NOTE: If the well management data is not entered, the option entered will apply for all members of all well management levels.

Alpha label indicating the level of the well management hierarchy to which the specified option applies:



AREA Area.

FIELD Field.


Alpha label indicating the option is specified for:

O Oil phase.

W Water phase.

G Gas phase.

L Liquid phase.

4-232 5000.4.4


Alpha label indicating the action to be taken when the sum of the oil deliverabilities of producing wells exceeds the specified phase targets:

SCALE Scale the rates of all wells to exactly hit the target. This is the default if the TRGOPT card is omitted for oil and liquid targets. This option can be selected for any phase target.

AVG Reset the rates of appropriate wells to an average rate.

That is, if a well’s oil rate is designated as WPOi*

, then

the reset rates will be

WPOi*

= min (WPOi , AVG),

where AVG has been computed to satisfy

Oil Target = WPOi*

i

This option can be selected for any phase target.

GOR Reduce the production rate of the highest GOR wells to a user-specified minimum rate (TRGQMN card) until the phase target is reached. This is the default if the TRGOPT card is omitted for gas target.

WCUT Reduce the production rate of the highest water-cut wells to a user-specified minimum rate (TRGQMN card) until the phase target is reached. This is the default if the TRGOPT card is omitted for water target.

WRATE Reduce the production rate of the highest water rate wells to a user-specified minimum rate (TRGQMN card) until the phase target is reached.

GRATE Reduce the production rate of the highest gas rate wells to a user-specified minimum rate (TRGQMN card) until the phase target is reached.

AVGGOR For gas target, reset the rates of appropriate wells to an average rate based on GOR; the set of wells to be reduced will be those whose GOR is above a calculated target. For oil and liquid targets, scale back the highest GOR wells.

AVGWOR Reset the rates of appropriate wells to an average rate based on water-oil ratio. The set of wells to be reduced will be those whose water-oil ratio is above a calculated target. This option can only be selected for water target.

AVGLOR Reset the rates of appropriate wells to an average rate based on liquid-oil ratio. The set of wells to be reduced

5000.4.4 4-233


will be those whose liquid-oil ratio is above a calculated target. This option can only be selected for liquid target.

AVGWCT Scale back the highest water-cut wells. This option can only be selected for oil and liquid targets.

NOTE: When entered, one and only one of the GATHER, FLOSTA, AREA, or FIELD labels can be specified. There is no default. When FIELD is specified the inum entry may be omitted, or the value 1 may be input; no other value will be accepted.One and only one of the O, W, G, or L labels must be specified. There is no default. Separate options can be specified for oil, water, gas, and liquid by reading multiple TRGOPT cards.One and only one of the SCALE, AVG, GOR, WCUT, WRATE, GRATE, AVGGOR, AVGWOR, AVGLOR, or AVGWCT labels must be specified.A well’s rate is never reduced below trgqmn by the SCALE, GOR, WCUT, WRATE, and GRATE methods. The AVG, AVGGOR, AVGWOR, AVGLOR, and AVGWCT methods can drop a well below trgqmn, although it is highly unlikely this would ever occur.The options specified on a TRGOPT card for gas and water phase targets are ignored when GASWAT has been chosen on the TRGORD card. In this case the rate at the highest GOR well is reduced to TRGQMN, then the rate of the highest water-cut well is reduced to TRGQMN, then the next highest GOR well, then the next highest water-cut well, etc., until the target(s) is (are) met.

4-234 5000.4.4


4.3.5 Order for Checking Phase Targets (TRGORD)

00 The TRGORD card is used in conjunction with the PTARG and TRGOPT cards to define the order for reducing the various phase rates of wells to meet specified phase production targets.

TRGORD

GATHER

FLOSTA

AREA

FIELD

inum

OIL GAS LIQUID WATER

OIL LIQUID GASWAT

00 Definitions:

NOTE: If the well management data is not entered, the ordering entered will apply for all members of all well management levels.

Alpha label indicating the level of the well management hierarchy to which the specified ordering applies:



AREA Area.

FIELD Field.


Alpha label indicating the option is specified for checking targets for:

OIL Oil phase.

GAS Gas phase.

LIQUID Liquid phase.

WATER Water phase.

GASWAT Gas and water simultaneously. This method involves decreasing rates of wells to TRGQMN until the target(s) is (are) met in the following order: highest GOR, highest water-cut, next highest GOR, etc.

5000.4.4 4-235


NOTE: When entered, one and only one of the GATHER, FLOSTA, AREA, or FIELD labels can be specified. There is no default. When FIELD is specified the inum entry may be omitted, or the value 1 may be input; no other value will be accepted.The default ordering is: OIL GAS LIQUID WATERThe TRGORD card can only be used in one of the formats described above; i.e., either the four OIL, WATER, GAS, and LIQUID labels must be specified or the OIL, LIQUID, and GASWAT labels must be specified - each set of labels can be in any order. The order in which phases are specified determines the order in which various phase targets are checked at each level of well management, starting from the gathering center.

4-236 5000.4.4


4.3.6 Minimum Rate for Use in Targeting Calculations (TRGQMN)

00 A TRGQMN card is used to define the minimum rate to which the well rate is cut back when a phase target is being satisfied at any well management level.

TRGQMN

O

G

W

LIQUID

wl

trgqmn1 trgqmn2 ... trgqmnn

00 Definitions:

Alpha label indicating the minimum production rates are being specified for:

O Oil phase, STB/D (STM3/D).

G Gas phase, MSCF/D (SM3/D).

W Water phase, STB/D (STM3/D).

LIQUID Liquid phase, STB/D (STM3/D).

wl List of wells for which trgqmn values are being specified (see Section 1.5.2).

trgqmn Minimum rate to which the well’s rate is cut back when meeting a phase target. Default is 0.

NOTE: The number of trgqmn values must equal the number of wells in the well list.

00 Examples:

00 TRGQMN O 2 -14 18 22 24 -37 4130*0.0

5000.4.4 4-237


4.3.7 Well Rate Maximum Tolerances (TRGTOL)

00 The TRGTOL card is used to specify the factor by which each of the oil, gas water, and liquid maxima may be exceeded before violations occur.

TRGTOL

GATHER

FLOSTA

AREA

FIELD

inum

opttol gpttol wpttol (lpttol)

00 Definitions:

NOTE: If the well management data is not entered, the tolerances entered will apply for all members of all well management levels.

Alpha label indicating the level of the well management hierarchy to which the specified tolerances applies:



AREA Area.

FIELD Field.


opttol Factor by which oil maxima may be exceeded before a violation occurs. Default is 0.05.

gpttol Factor by which gas maxima may be exceeded before a violation occurs. Default is 0.05.

wpttol Factor by which water maxima may be exceeded before a violation occurs. Default is 0.05.

lpttol Factor by which liquid maxima may be exceeded before a violation occurs. Default is 0.05.

NOTE: When entered, one and only one of the GATHER, FLOSTA, AREA, or FIELD labels can be specified. There is no default. When FIELD is specified the inum entry may be omitted, or the value 1 may be input; no other value will be accepted

4-238 5000.4.4


4.3.8 Injection Target (ITARG)

00 An ITARG card is used to define a maximum injection rate for a gathering center, a flow station, an area, the field, or an injection region.

ITARG

GATHER

FLOSTA

AREA

FIELD

INJREG

inum W

Gqtarg

00 Definitions:

Alpha label indicating the level of the well management hierarchy to which the specified maximum injection rate applies:



AREA Area.

FIELD Field.

INJREG Injection region.



W Water injection, STB/D (STM3/D).

G Gas injection, MSCF/D (SM3/D).

qtarg Maximum injection rate.

NOTE: 1. One and only one of the GATHER, FLOSTA, AREA, FIELD, or INJREG labels must be specified. There is no default. When FIELD is specified the inum entry may be omitted, or the value 1 may be input; no other value will be accepted.

2. One and only one of the W or G labels must be specified. There is no default. Separate maxima can be established for water and gas by reading multiple ITARG cards.

3. The maximum rate criteria are satisfied first at the gathering center level, then the flow station level, then the area level, and finally at the field level.

5000.4.4 4-239


4. All wells in the tested level are cut by the same factor if there is an excess of injectivity (unless the UNIFORM option is used).

5. Wells whose rates have been reduced due to targeting are designated by WTAR (or GTAR) in the injection well summary.

6. Well rates will never be reduced below qmin.

7. When the injection region option is used, the ITARG cards for the other well management levels (gathering center, flow station, area) are ignored.

00 Example:

00 ITARG INJREG 1 W 50000ITARG INJREG 2 W 50000ITARG INJREG 1 G 70000ITARG INJREG 2 G 70000

4.3.9 Well Rate Scaleback Options with Targeting (LSCALE)

00 An LSCALE card is used to change the procedure that is used to recalculate the layer rates for multi-perforation wells whose rates are being reduced to meet specified targets. The keyword LSCALE is derived from linear scaling, and will determine whether the perforation rates are scaled back linearly, or whether they are rigorously recalculated.

LSCALE ON

OFF

4-240 5000.4.4


00 Definitions:

00 Alpha label indicating the procedure to be used:

ON Use linear scaling of each of the perforation rates of each well by its respective rate reduction factor.

OFF Recalculate the perforation rates for each well based on its reduced total well rate, maintaining an equilibrium bottomhole flowing pressure profile. This is the default procedure.

NOTE: The specified procedure is used for both production targets and injection targets.

5000.4.4 4-241


4.4 Minimum Rates

4.4.1 Minimum Production Rates (PRDMIN)

00 A PRDMIN card is used to define a minimum production rate for a gathering center, a flow station, an area, or the field. When this value is violated in a member of one of these levels, this member is "shut-in". This means that all of the producers, or all of the wells, attached to that member of the well management hierarchy are shut-in.

PRDMIN

GATHER

FLOSTA

AREA

FIELD

inumO

W

G

prdminALL

ONLY

00 Definitions:

Alpha label indicating the level of the well management hierarchy to which the specified minimum production rate applies:



AREA Area.

FIELD Field.


Alpha label indicating the minimum rate is based on:




prdmin Minimum production rate.

ALL Alpha label indicating all wells in member inum are shut in if the minimum rate is not met. This is the default.

ONLY Alpha label indicating only the production wells in member inum are shut in if the minimum rate is not met.

4-242 5000.4.4



2. One and only one of the O, W, or G labels must be specified. There is no default. Separate minima can be established for oil, water, and gas by reading multiple PRDMIN cards.

3. The minimum rate criteria are satisfied first at the gathering center level, then the flow station level, and then the area level.

4. The minimum rate criteria at the field level is checked after the successful completion of each timestep. If any field minimum constraint is violated, a restart record is written and the run is terminated. This restart record contains the data from the beginning of this timestep. This will happen regardless of whether ALL or ONLY is specified.

5. When starting from the restart record described in the previous note, remember that the specified minima will still be in effect. Unless the minima are decreased or more production brought online, the field will immediately shut in.

4.4.2 Minimum Injection Rates (INJMIN)

00 An INJMIN card is used to define a minimum injection rate for a gathering center, a flow station, an area, or the field. When this value is violated in a member of one of these levels, this member is "shut-in". This means that all of the injectors, or all of the wells, attached to that member of the well management hierarchy are shut-in.

INJMIN

GATHER

FLOSTA

AREA

FIELD

inum W

Ginjmin

ALL

ONLY

00 Definitions:

Alpha label indicating the level of the well management hierarchy to which the specified minimum injection rate applies:



AREA Area.

5000.4.4 4-243


FIELD Field.


Alpha label indicating the minimum rate is based on:

W Water injection, STB/D (STM3/D).

G Gas injection, MSCF/D (SM3/D).

injmin Minimum injection rate.

ALL Alpha label indicating all wells in member inum are shut in if the minimum rate is not met. This is the default.

ONLY Alpha label indicating only the water (or gas) injection wells in member inum are shut in if the minimum rate is not met.


2. One and only one of the W or G labels must be specified. There is no default. Separate minima can be established for water and gas by reading multiple INJMIN cards.

3. The minimum rate criteria are satisfied first at the gathering center level, then the flow station level, and then the area level.

4. The minimum rate criteria at the field level is checked after the successful completion of each timestep. If any field minimum constraint is violated, a restart record is written and the run is terminated. This restart record contains the data from the beginning of the timestep. This will happen regardless of whether ALL or ONLY is specified.

5. When starting from the restart record described in the previous note, remember that the specified minima will still be in effect. Unless the minima are decreased or more injection brought online, the field will immediately shut in.

4-244 5000.4.4


4.5 Gas Cycling (Not available in VIP-THERM)

4.5.1 Shrinkage Gas Specification (GASSKG)

00 The GASSKG card is used to specify the shrinkage gas rate to be removed from the total surface production rate of gas for use with gas injectors on any of the reinjection options.

GASSKG

GATHER

FLOSTA

AREA

FIELD

inum [QRATE q] [FPROD f]

00 Definitions:

Alpha label indicating the level of the well management hierarchy to which the specified shrinkage gas rate applies:



AREA Area.

FIELD Field.


QRATE Shrinkage gas rate, MSCF/D (SM3/D).

q Fixed rate.

FPROD Fraction of the total surface production rate to be used as the shrinkage gas rate.

f Fraction of production rate.

NOTE: One and only one of the GATHER, FLOSTA, AREA, or FIELD levels must be specified. There is no default. When FIELD is specified the inum entry may be omitted, or the value 1 may be input; no other value will be accepted.Data specified at the lower level of well management will be added to that at the higher level of well management.If both the QRATE and FPROD labels are specified, the shrinkage gas rate

5000.4.4 4-245


is the specified rate plus the fraction of the surface production rate. (q + f * the surface production rate).

00 Examples:

00 C ***** SHRINKAGE GAS RATECGASSKG GATHER 1 QRATE 100. FPROD 0.1

4.5.2 Fuel Gas Specification (GASFUL)

00 The GASFUL card is used to specify the fuel gas rate to be removed from the total surface production rate of gas for use with gas injectors on any of the reinjection options.

GASFUL

GATHER

FLOSTA

AREA

FIELD

inum [QRATE q] [FPROD f] (PLANT)

00 Definitions:

Alpha label indicating the level of the well management hierarchy to which the specified fuel gas rate applies:



AREA Area.

FIELD Field.


QRATE Fuel gas rate, MSCF/D (SM3/D).

q Fixed rate. If a GASCOND card is input and the number of the member in the well management level specified on this GASFUL card is also specified on a PLANT card, q will be the amount excluding component icomp identified or the GASCOND card.

FPROD Fraction of the total surface production rate to be used as the fuel gas rate.

4-246 5000.4.4


f Fraction of production rate. If a GASCOND card is input and the number of the member in the well management level specified on this GASFUL card is also specified on a PLANT card, the production rate to which the fraction applies will be the amount excluding component icomp identified or the GASCOND card.

PLANT Alpha label indicating that the fuel gas specified on this card will be removed from the outlet gas stream of the MI plant. If this label is omitted, the fuel gas will be removed from the production gas stream (prior to any plant calculation).

NOTE: One and only one of the GATHER, FLOSTA, AREA, or FIELD levels must be specified. There is no default. When FIELD is specified the inum entry may be omitted, or the value 1 may be input; no other value will be accepted.Data specified at the lower level of well management will be added to that at the higher level of well management.If both the QRATE and FPROD labels are specified, the fuel gas rate is the specified rate plus the fraction of the surface production rate. (q + f * the surface production rate).Up to two GASFUL cards may be input for any member of a well management level: one with and the other without the alpha label PLANT. In this case, two fuel gas streams will be removed: one from the produced gas stream and the other from the outlet gas stream of the MI plant.

00 Examples:

00 C ***** FUEL GAS RATECGASFUL GATHER 1 QRATE 200. FPROD 0.1GASFUL GATHER 1 QRATE 300. PLANT

5000.4.4 4-247


4.5.3 Sales Gas Specification (GASSLS)

00 The GASSLS card is used to specify the sales gas rate to be removed from the total surface production rate of gas for use with gas injectors on any of the reinjection options.

GASSLS

GATHER

FLOSTA

AREA

FIELD

inum [QSALES q][FPROD f] [FPO gor] (PLANT)

00 Definitions:

Alpha label indicating the level of the well management hierarchy to which the specified sales gas rate applies:



AREA Area.

FIELD Field.


QSALES Sales gas rate, MSCF/D (SM3/D).

q Fixed rate.

FPROD Fraction of the total surface production rate to be used as the sales gas rate.


FPO Fraction of the total surface oil production rate to be used as the sales gas rate.

gor Fraction of oil production rate in GOR units, MSCF/STB (SM3/STM3).

PLANT Alpha label indicating that a gas conditioning plant will be included to process the sales gas where component icomp on the PLANT card will be removed from the sales gas stream. In this case, the value q on this GASSLS card and the production rate to which the fraction f applies represent the component icomp-free

4-248 5000.4.4


amount. The removed component icomp amount will be recombined with the reinjected gas stream.

NOTE: One and only one of the GATHER, FLOSTA, AREA, or FIELD levels must be specified. There is no default. When FIELD is specified the inum entry may be omitted, or the value 1 may be input; no other value will be accepted.Data specified at the lower level of well management will be added to that at the higher level of well management.The sales gas rate is the specified rate plus the fraction of the surface gas production rate plus the fraction of the surface oil production rate. (q + f * the surface gas production rate + gor * the surface oil production rate). The default values for q, f, and gor are zero.

00 Examples:

00 C ***** SALES GAS RATECGASSLS GATHER 1 QSALES 500. FPROD 0.7GASSLS GATHER 2 FPO 0.5

4.5.4 Makeup Gas Specification (GASMKP)

00 The GASMKP card is used to specify the maximum makeup gas rate to be added to the pool of gas available for reinjection (produced minus sales minus shrinkage minus fuel) for use with gas injectors on any of the reinjection options.

GASMKP

GATHER

FLOSTA

AREA

FIELD

inum QMAKE q

QPOOL q

FPROD f

FSALES f

00 Definitions:

Alpha label indicating the level of the well management hierarchy to which the specified makeup gas rate applies:



AREA Area.

FIELD Field.

5000.4.4 4-249



QMAKE Maximum makeup gas rate, MSCF/D (SM3/D).

QPOOL Total injected gas rate, MSCF/D (SM3/D). The maximum makeup gas rate would be: (pool rate + sales rate + shrinkage rate + fuel rate - production rate).

q Gas rate.

FPROD Fraction of the total surface production rate to be used as the makeup gas rate.

FSALES Fraction of the sales gas rate to be used as the makeup gas rate.


NOTE: One and only one of the GATHER, FLOSTA, AREA, or FIELD levels must be specified. There is no default. When FIELD is specified the inum entry may be omitted, or the value 1 may be input; no other value will be accepted.Data specified at the lower level of well management will be added to that at the higher level of well management.Only one of the FPROD or FSALES labels can be specified.If both the QMAKE and FPROD labels are specified, the makeup gas rate is the specified rate plus the fraction of the production rate. (q + f * the surface production rate).If both the QMAKE and FSALES labels are specified, the makeup gas rate is the specified rate plus the fraction of the sales gas rate. (q + f * the sales gas rate).Neither the FPROD nor the FSALES labels can be specified with the QPOOL label.When the QPOOL option is specified, the makeup gas rate will not be allowed to be negative. That is, the pool rate is not allowed to be less than the production rate minus the sales rate minus the shrinkage rate minus the fuel gas rate.Either a YINJMK card or a YREINJ card must be specified for the same member of the well management level input on the GASMKP card. The required volume of makeup gas at this composition will be added to the produced gas available for reinjection to compute the overall composition of the injected gas.

00 Examples:

4-250 5000.4.4


00 C ***** MAKEUP GAS RATECGASMKP GATHER 1 QMAKE 100. FPROD 0.2GASMKP GATHER 2 QPOOL 300.

4.5.5 Makeup MI Specification (MIMKP)

00 For the four-component miscible option, the MIMKP card is used to specify the makeup MI rate to be added to the pool of MI available for reinjection for use with MI injectors on any of the reinjection options.

MIMKP

GATHER

FLOSTA

AREA

FIELD

inum QMAKE q

00 Definitions:

Alpha label indicating the level of the well management hierarchy to which the specified makeup MI rate applies:



AREA Area.

FIELD Field.


QMAKE Makeup MI rate, MSCF/D (SM3/D)

q MI rate.

NOTE: 1. One and only one of the GATHER, FLOSTA, AREA, or FIELD levels must be specified. There is no default. When FIELD is specified the inum entry may be omitted, or the value 1 may be input; no other value will be accepted.

2. Data specified at the lower level of well management will be added to that at the higher level of well management.

3. This card may be input only if the four-component miscible option is invoked.

5000.4.4 4-251


00 Example:

00 C*****MAKEUP MI RATECMIMKP FIELD QMAKE 500.

4.5.6 Effective Gas Injection Target (ETRGOP)

00 The ETRGOP card is used to select the method of checking the total gas injection rate for each level of well management. The effective target is defined as the minimum of the gas available for reinjection and the user-specified injection target.

ETRGOP

ALL

FIELD

NONE

00 Definitions:

ALL Effective target is checked for all levels of well management.

FIELD Effective target is checked for the field level only.

NONE Effective target is not used. This is the default.

NOTE: When the ALL option is selected, the effective target instead of the specified target will be checked at all levels of well management. When the FIELD option is selected, the specified injection target will be checked at each gathering center, flow station, and area. The effective target will be checked at the field level. When the NONE option is selected, the specified injection target will be checked at each level of well management.When the general injection region option is used, the ETRGOP card will be neglected. The specified injection target will be checked in each injection region. Then, the effective target will be checked at the field level.

00 Examples:

00 C *****EFFECTIVE TARGETETRGOP FIELD

4-252 5000.4.4


4.5.7 Makeup Gas Composition (YINJMK)

00 The YINJMK card is used to specify the composition of the makeup gas for use with gas injectors on any of the reinjection options.

YINJMK

GATHER

FLOSTA

AREA

FIELD

inum (PROD) (card 1)yinjmk1 yinjmk2 . . . yinjmknc (card 2)

00 Definitions:

Alpha label indicating the level of the well management hierarchy to which the specified gas composition applies:



AREA Area.

FIELD Field.


PROD Alpha label indicating that the composition of the produced gas should be used as the composition of the makeup gas. If a composition is input on the following card, it will be ignored.

yinjmkk Mole fraction of component k in the gas. A value must be specified for each of the components, and the values must sum exactly to 1.0. This data need not be input if PROD was specified.

NOTE: 1. One and only one of the GATHER, FLOSTA, AREA, or FIELD labels must be specified. There is no default. When FIELD is specified the inum entry may be omitted, or the value 1 may be input; no other value will be accepted.

2. A YINJMK card or a YREINJ card for the appropriate level of the well management hierarchy must be entered when the GASMKP card is input.

5000.4.4 4-253


3. As many data cards (card 2) as necessary may be used to specify a yinjmk value for each component.

4.5.8 Reinjected Gas Composition (YREINJ)

00 The YREINJ card is used to specify the composition of the reinjected gas for use with gas injectors on any of the reinjection options.

YREINJ

GATHER

FLOSTA

AREA

FIELD

inum (PROD)

yreinj1 yreinj2 ... yreinjnc

00 Definitions:

Alpha label indicating the level of the well management hierarchy to which the specified gas composition applies:



AREA Area.

FIELD Field.


PROD Alpha label indicating that the composition of the produced gas should be used as the composition of the reinjected gas. If a composition is input on the following card, it will be ignored.

yreinjk Mole fraction of component k in the gas. A value must be specified for each of the components, and the values must sum exactly to 1.0. This data need not be input if PROD was specified.


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2. The data on the YREINJ card overrides the composition of the reinjected gas calculated internally.

3. A YINJMK card or a YREINJ card for the appropriate level of the well management hierarchy must be entered when the GASMKP card is input.

4. As many data cards as necessary may be used to specify a yreinj value for each component.

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4.5.9 Reinjection Gas Composition When Zero Production (YZERO)

00 The YZERO card is used to set a composition to be used for reinjection gas composition based on the produced gas composition (from the YINJMK, YREINJ, YINJ cards), but for whatever reason the produced gas rate is zero. If the YZERO card is not entered, when this condition occurs the program terminates.

YZERO

GATHER

FLOSTA

AREA

FIELD

inum (LAST)

yzero1 yzero2 ... yzeronc

00 Definitions:

Alpha label indicating the level of the well management hierarchy to which the instruction for zero produced gas applies:



AREA Area.

FIELD Field.


LAST Alpha label indicating that the most recently computed reinjection gas composition is to be used when there is no produced gas. If not entered, the composition to be used is entered on the next card.

yzerok Mole fraction of component k in the gas. A value must be specified for each of the components, and the values must sum exactly to 1.0. If LAST was not entered, this data is required and is defined as the reinjection gas composition to be used if the produced gas rate is zero. If LAST was entered, this is the composition that will be used if the program has not yet computed a reinjection gas composition in any previous timestep. If a set of compositions is not entered with LAST, the fallback composition will be 1.0, 0.0, 0.0, ...

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2. As many data cards as necessary may be used to specify a yzero value for each component.

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4.5.10 Liquid Recovery Factors (RECFAC)

00 The RECFAC card is used to specify the fraction of each component in the gas stream that can be recovered as a liquid at the gas plant for use with gas injectors on any of the reinjection options. Alternatively, if the four-component miscible option is invoked, the input recovery factor for component 3 will be treated as the MI recovery factor and the recovered MI (plus makeup MI, if applicable) will be used for MI injectors (see INJ card, Section 3.4.2).

RECFAC recfac1 recfac2 . . . recfacnc

00 Definition:

recfack Fraction of component k in the gas stream that can be recovered as a liquid at the gas plant. A value must be specified for each of the components. For the four-component miscible option, recfac will be treated as the MI recovery factor for MI reinjection.

NOTE: 1. If the RECFAC card is not entered, the fractions are assumed to be 0.0.

2. As many data cards (card 2) as necessary may be used to specify a recfac value for each component.

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4.5.11 Invoke Major Gas Sales Option (PLANT)

00 The PLANT card is used to invoke the major gas sales option and to specify the member of the well management hierarchy for which the major gas sales algorithm applies.

PLANTON

OFF

GATHER

FLOSTA

AREA

FIELD

iwmll

00 Definitions:

Alpha label indicating the major gas sales option (NGLPLANT, MIPLANT, or GASCOND card) is to be applied to the numbers of the members in the well management level specified on this card:

ON The major gas sales calculation is to be performed for the well management level specified on this card.

OFF The major gas sales calculation will not be performed for the well management level specified on this card. This is the default.

Alpha label indicating well management level:

GATHER Gathering Center.


AREA Area.

FIELD Field.

iwmll List of numbers of the members in the specified well management level. If FIELD is the specified well management level, iwmll must be omitted.

NOTE: The major gas sales calculation will be performed only for those members of the well management hierachy explicitly appearing on a PLANT card.

00 Examples:

00 PLANT ON GATHER 1 3 -6PLANT ON FIELD

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4.5.12 Gas Conditioning for Sales Gas and Fuel Gas (GASCOND)

GASCOND icomp (VENT)(DIST idist)

00 Definition:

icomp Hydrocarbon component number to be removed from the sales gas stream in the gas conditioning plant, if the keyword PLANT is specified on the GASSLS card. Also, all input (GASFUL card) and output fuel gas amounts will exclude amounts of component icomp (i.e., component icomp-free amounts).

VENT Alpha label indicating that component icomp removed from the sales gas stream will not be combined with the reinjected gas stream and will be vented.

DIST Alpha label indicating that component icomp removed from the sales gas stream will not be combined with the reinjected gas stream and will be uniformly distributed into a user-specified number of FSTD gas injectors (Type A injectors identified by keyword KEYCMP in the INJ card) using Method idist. Keyword DIST may be specified only if a GINJOP UNIFORM card is also specified.

idist Integer 1 through 3 indicating method number for the distribution of the reinjected gas stream and component icomp stream into FSTD gas injectors. In all three methods, component icomp stream will be uniformly distributed into all above mentioned Type A injectors. In Method 1, the reinjected gas stream will be uniformly distributed into all FSTD gas injectors not identified as Type A injectors (i.e., Type B injectors). In Method 2, the reinjected gas stream will be distributed into all FSTD gas injectors (i.e., all Type A and Type B injectors) with the constraint that all injectors have the same total gas (component icomp and/or reinjected gas) injection rate. In Method 3, the reinjected gas stream will be uniformly distributed into all FSTD gas injectors (i.e., all Type A and Type B injectors). If the component icomp and/or the reinjected gas rate exceeds the total injectivity and cutback of the injection rate is necessary, the component icomp stream will be vented first.

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NOTE: In the major gas sales option, the GASCOND card is used to remove one component (e.g., CO2) from a sales gas stream. The removed component amount will then either be recombined with the reinjected gas (i.e., the outlet gas stream of the MI plant and any available makeup gas), vented (through keyword VENT), or uniformly distributed into Type A gas injectors (through keyword DIST). The DIST option may be specified only if the UNIFORM method in the gas reinjection option (GINJOP card) is chosen. If both VENT and DIST are not specified, the component icomp stream will be recombined with the reinjected gas stream for reinjection. Furthermore, the input fuel gas amount on the GASFUL card and the output fuel gas amount in the gas handling report are component icomp-free amount.

00 Examples:

00 GASCOND 2 DIST 2

4.5.13 Natural Gas Liquid (NGL) Plant Data Input (NGLPLANT)

00 The NGLPLANT card is used in the major gas sales option to allow the produced gas stream (minus fuel and shrinkage gas) in any well management level to be processed in an NGL plant to remove NGL from the stream.

NGLPLANTNKEY ikey (PLUS)KEYCMPvkcmp1 vkcmp2 ... vkcmpj ... vkcmpNI(enter number of KEY component plus composition values forinterpolation. j=1 to number of interpolation points, NI)PLNTRYpr1,1 pr1,2 ... pr1,j ... pr1,NIpr2,1 pr2,2 ... pr2,j ... pr2,NI. . . .. . . .pri,1 pri,2 ... pri,j ... pri,NI. . . prNC,1 prNC,2 ... prNC,j ... prNC,NI(enter the plant liquid molar recovery fractions for each interpolation point, j=1 to number of interpolation values, NI and repeat for all components, i=1 to the number of components, NC)

00 Definitions:

NKEY Alpha label indicating that the key component number or the key component plus fraction number is to be read. The cards KEYCMP and PLNTRY defined below should follow the NKEY card.

ikey The number of the key component or the key component plus fraction to be used in the liquid recovery fraction

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table look up. In the key component case, the mole fraction of the key component is used for the table look up of component liquid recovery values, whereas in the key component plus fraction case, the sum of the well stream over all mole fraction from the key component plus all the following components are used in the table look up.

PLUS Alpha label indicating the key component plus fraction is to be used in the table look up.

KEYCMP Alpha label indicating the key component mole fractions or the key component plus over all mole fractions are to be entered. These are the key component mole fractions or the sum of key component plus mole fractions that are to be used in the liquid recovery fraction table look up.

vkcmp The value of the key component mole fraction or the sum of the key component plus fraction to be used as an interpolation value. There are NI number of interpolation point values to be read. They should be on one card and should cover the range of values that are to be expected in the run. The range of values on this card should be between 0. and 1. NI is determined by the number of values read on the card. The vkcmp values on this card must be in descending order.

PLNTRY Alpha label indicating that the separate liquid recovery fractions will be entered. The liquid recovery fraction is the molar fraction of the component that will be separated to the liquid stream.

pr The fraction of the component that will be separated to the liquid stream in the NGL Plant. The liquid recovery fractions are entered for each component as a function of the key component mole fraction or the key component plus mole fraction and one value must be entered for NI points and for each component. The data must be ordered so that the liquid recovery fractions should be entered for component 1 for all values of key component plus fraction interpolation points (NI). The next card is for component 2 recovery fractions at NI points. This continues until all component values have been read. In all there should be (NI * NC) values read. The values must be between 0. and 1.

NOTE: In the major gas sales option, the produced gas stream in any well management level may be processed in an NGL plant and/or a MI plant to remove NGL and/or MI. Sales gas is then removed from the output gas stream, and the remaining gas is combined with the makeup gas to form

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the reinjected gas stream.The feed composition of an NGL plant (or an MI plant if no NGL plant included) is the composition of the total stock tank gas stream for any well management level, while output NGL and gas streams are determined by the molar liquid recovery fractions. If a MIPLANT tables is also input, the output gas stream from the NGLPLANT will be fed into the MIPLANT. The outlet MI composition from the MI plant for well management level will be used as the injection composition for MI injectors attached to the level (see the INJ card).A PLANT card must be entered to invoke the NGL calculation for any well management level. The feed, outlet liquid (NGL and gas rates and compositions can be printed as part of the separator report using the keyword SEP on the PRINT card.

00 Examples:

00 C=========================================C NGL PLANT C =========================================NGLPLANTNKEY 6 PLUSKEYCMPC DEFINE KEY COMPONENT PLUS FRACTIONS (NC = 6 TO 8)C NUMBER OF INTERPOLATION POINTS (NI= 11).9999 .108 .104 .098 .075 .065 .047 .028 .018 .010 .000PLNTRYC DEFINE COMPONENT LIQUID RECOVERIES (NI = 11, NC =8).0240 .0240 .0240 .0220 .0170 .0140 .0100 .0050 .0030 .0020 .0020.0070 .0070 .0070 .0060 .0050 .0040 .0030 .0010 .0010 .0000 .0000.0610 .0610 .0590 .0560 .0430 .0370 .0270 .0140 .0090 .0060 .0060.1790 .1790 .1750 .1690 .1370 .1220 .0920 .0550 .0400 .0290 .0290.4680 .4680 .4640 .4530 .4000 .3710 .3050 .2200 .1770 .1480 .1480.9960 .9960 .9960 .9960 .9940 .9930 .9890 .9790 .9690 .9590 .95901.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.0001.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000

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4.5.14 Miscible Injectant (MI) Plant Data Input (MIPLANT)

00 The MIPLANT card is used in the major gas sales option to allow the produced gas stream (minus fuel and shrinkage gas) in any well management level to be processed in an MI plant to remove MI from the stream.

MIPLANTNKEY ikey (PLUS)KEYCMPvkcmp1 vkcmp2 ... vkcmpj ... vkcmpNI(enter number of KEY component plus composition values forinterpolation. j=1 to number of interpolation points, NI)PLNTRYpr1,1 pr1,2 ... pr1,j ... pr1,NIpr2,1 pr2,2 ... pr2,j ... pr2,NI. . . .. . . .pri,1 pri,2 ... pri,j ... pri,NI. . . prNC,1 prNC,2 ... prNC,j ... prNC,NI(enter the plant liquid molar recovery fractions for each interpolation point, j=1 to number of interpolation values, NI and repeat for all components, i=1 to the number of components, NC)

00 Definitions:


ikey The number of the key component or the key component plus fraction to be used in the liquid recovery fraction table look up. In the key component case, the mole fraction of the key component is used for the table look up of component liquid recovery values, whereas in the key component plus fraction case, the sum of the well stream over all mole fraction from the key component plus all the following components are used in the table look up.

PLUS Alpha label indicating the key component plus fraction is to be used in the table loop up.


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pr The fraction of the component that will be separated to the liquid stream in the MI Plant. The liquid recovery fractions are entered for each component as a function of the key component mole fraction or the key component plus mole fraction and one value must be entered for NI points and for each component. The data must be ordered so that the liquid recovery fractions should be entered for component 1 for all values of key component plus fraction interpolation points (NI). The next card is for component 2 recovery fractions at NI points. This continues until all component values have been read. In all there should be (NI * NC) values read. The values must be between 0. and 1.

NOTE: In the major gas sales option, the produced gas stream in any well management level may be processed in an NGL plant and/or a MI plant to remove NGL and/or MI. Sales gas is then removed from the output gas stream, and the remaining gas is combined with the makeup gas to form the reinjected gas stream.The feed composition of an NGL plant (or an MI plant if no NGL plant included) is the composition of the total stock tank gas stream for any well management level, while output NGL and gas streams are determined by the molar liquid recovery fractions. If a MIPLANT tables is also input, the output gas stream from the NGLPLANT will be fed into the MIPLANT. The outlet MI composition from the MI plant for well management level will be used as the injection composition for MI injectors attached to the level (see the INJ card).A PLANT card must be entered to invoke the MI calculation for any well management level. The feed, outlet liquid (MI and gas rates and compositions can be printed as part of the separator report using the keyword SEP on the PRINT card. The MI plant summary table also contains the reinjected lean gas

5000.4.4 4-265


composition.

00 Examples:

00 C=========================================C MI PLANT C =========================================MIPLANTNKEY 6 PLUSKEYCMPC DEFINE KEY COMPONENT PLUS FRACTIONS (NC = 6 TO 8)C NUMBER OF INTERPOLATION POINTS (NI= 11).9999 .108 .104 .098 .075 .065 .047 .028 .018 .010 .000PLNTRYC DEFINE COMPONENT LIQUID RECOVERIES (NI = 11, NC =8).0240 .0240 .0240 .0220 .0170 .0140 .0100 .0050 .0030 .0020 .0020.0070 .0070 .0070 .0060 .0050 .0040 .0030 .0010 .0010 .0000 .0000.0610 .0610 .0590 .0560 .0430 .0370 .0270 .0140 .0090 .0060 .0060.1790 .1790 .1750 .1690 .1370 .1220 .0920 .0550 .0400 .0290 .0290.4680 .4680 .4640 .4530 .4000 .3710 .3050 .2200 .1770 .1480 .1480.9960 .9960 .9960 .9960 .9940 .9930 .9890 .9790 .9690 .9590 .95901.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.0001.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000 1.000

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4.5.15 Liquified Petroleum Gas (LPG) Plant Data Input (LPGPLANT)

00 The LPGPLANT card is used in the major gas sales option to allow the produced gas stream (minus fuel and shrinkage gas) or the outlet gas from the NGLPLANT (if an NGLPLANT is specified) in any well management level to be processed in an LPG plant to remove LPG from the stream.

LPGPLANTNKEY ikey (PLUS)KEYCMPvkcmp1 vkcmp2 .... vkcmpj .... vkcmpNI(enter number of KEY component plus composition values forinterpolation. j=1 to number of interpolation points, NI)PLNTRYpr1,1 pr1,2 .... pr1,j .... pr1,NIpr2,1 pr2,2 .... pr2,j .... pr2,NI. . . . . .. . . . . .pri,1 pri,2 .... pri,j .... pri,NI. . . . . .prNC,1 prNC,2 .... prNC,j .... prNC,NI(enter the plant liquid molar recovery fractions for each interpolation point, j=1 to number of interpolation values, NI. Repeat for all components, i=1 to the number of components, NC)

00 Definitions:


ikey The number of the key component or the key component plus fraction to be used in the liquid recovery fraction table look up. In the key component case, the mole fraction of the key component is used for the table look up of component liquid recovery values, whereas in the key component plus fraction case, the sum of the well stream over all mole fraction from the key component plus all the following components are used in the table look up.

PLUS Alpha label indicating the key component plus fraction is to be used in the table loop up.


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pr The fraction of the component that will be separated to the liquid stream in the LPG Plant. The liquid recovery fractions are entered for each component as a function of the key component mole fraction or the key component plus mole fraction and one value must be entered for NI points and for each component. The data must be ordered so that the liquid recovery fractions should be entered for component 1 for all values of key component plus fraction interpolation points (NI). The next card is for component 2 recovery fractions at NI points. This continues until all component values have been read. In all there should be (NI * NC) values read. The values must be between 0. and 1.

NOTE: In the Major Gas Sales Option, the outlet gas stream of the NGL plant (if specified) is processed in the LPG plant. If a MIPLANT table is also input, the outlet gas stream from the LPG plant will be fed into the MI plant. The feed, outlet liquid (LPG) and gas rates and compositions can be printed as part of the separator report using keyword SEP on the PRINT card.

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4.5.16 Maximum Feed Rate to NGL Plant (NGLFED)

00 The NGLFED card specifies the maximum feed rate to the NGL plant for use with the NGLPLANT on the Major Gas Sales Option.

NGLFED

GATHER

FLOSTA

AREA

FIELD

inum QRATE q

00 Definitions:

Alpha label indicating the level of the well management hierarchy to which the specified maximum NGL feed rate applies:



AREA Area.

FIELD Field.


QRATE Maximum NGL feed rate, MSCF/D (SM3/D).

q Maximum rate.

NOTE: One and only one of the GATHER, FLOSTA, AREA, or FIELD levels must be specified. There is no default. When FIELD is specified the inum entry may be omitted, or the value 1 may be input; no other value will be accepted.Data specified at the lower level of well management will be added to that at the higher level of well management.

00 Examples:

C***** Maximum NGL Feed RateCNGLFED FIELD QRATE 100000.

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4.5.17 Maximum NGL Rate (NGLOUT)

00 The NGLOUT card specifies the maximum NGL rate from the NGL plant for use with the NGLPLANT on the Major Gas Sales Option.

NGLOUT

GATHER

FLOSTA

AREA

FIELD

inum QRATE q

00 Definitions:

Alpha label indicating the level of the well management hierarchy to which the specified maximum NGL rate applies:



AREA Area.

FIELD Field.


QRATE Maximum NGL rate, MSCF/D (SM3/D).

q Maximum rate.


00 Examples:

C***** Maximum NGL RateCNGLOUT AREA 1 QRATE 10000.

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4.5.18 Maximum Feed Rate to LPG Plant (LPGFED)

00 The LPGFED card specifies the maximum feed rate to the LPG plant for use with the LPGPLANT on the Major Gas Sales Option.

LPGFED

GATHER

FLOSTA

AREA

FIELD

inum QRATE q

00 Definitions:

Alpha label indicating the level of the well management hierarchy to which the specified maximum LPG feed rate applies:



AREA Area.

FIELD Field.


QRATE Maximum LPG feed rate, MSCF/D (SM3/D).

q Maximum rate.


00 Examples:

C***** Maximum LPG Feed RateCLPGFED FIELD QRATE 100000.

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4.5.19 Maximum LPG Rate (LPGOUT)

00 The LPGOUT card specifies the maximum LPG rate from the LPG plant for use with the LPGPLANT on the Major Gas Sales Option.

LPGOUT

GATHER

FLOSTA

AREA

FIELD

inum QRATE q

00 Definitions:

Alpha label indicating the level of the well management hierarchy to which the specified maximum LPG rate applies:



AREA Area.

FIELD Field.


QRATE Maximum LPG rate, MSCF/D (SM3/D).

q Maximum rate.


00 Examples:

C***** Maximum LPG RateCLPGOUT AREA 1 QRATE 10000.

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4.6 Basic Gas Reinjection (GINJOP) (Not Available in VIP-THERM)

00 A gas reinjection option other than the standard option of a well injecting a fraction of the production in a member in a well management level exists in VIP-EXECUTIVE. Under the new option, maximum rates are specified for the wells. If the sum of well injectivities exceeds the available reinjection gas, the rates are decreased by resetting the gas injection rates of appropriate wells to an average rate. That is, if a well’s rate is designated as WIGi, then the reset rates will be

00 WIGi*

= min (WIGi, AVG),

00 where AVG has been computed to satisfy

00 Gas Target = WIGi*

i

00 If the sum of well injectivities falls below the available reinjection gas, the gas injection rates of appropriate wells are scaled-up.

00 The GINJOP card is used to define the gas reinjection option to be used.

GINJOP STDUNIFORM

STD Alpha label indicating that the standard gas reinjection option is to be used. This is the default.

UNIFORM Alpha label indicating the gas reinjection option with uniform distribution of rate to wells to match the available reinjection gas rate will be used.

NOTE: 1. The GINJOP UNIFORM card must be entered before any QMAX cards.

2. For the UNIFORM option gas injection wells must be specified as either FSTD or FRES (INJ card), then assigned to the appropriate level of well management.

3. Also for the UNIFORM option the definition of qmax on the QMAX cards is the maximum gas injection rate, even though the well type is FSTD or FRES.

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4.7 Injection Regions (Not available in VIP-THERM)

00 Water and gas reinjection may be controlled through the use of injection regions. These are separate and independent of the other levels of well management to which water and gas injectors are assigned. Voidage replacement, pressure maintenance and gas project prioritization are allowed in the injection regions.

00 An injection region is defined by three dimensional grids. An injector can be assigned to one region only. An injector which does not physically exist within a region can still be assigned to it. If the user assigns gridblocks to injection regions but not the injection wells, the program assigns the injection region for the injector according to the location of the top perforation. A producer may be completed in more than one region. The program automatically matches the completion zones for a producer to the corresponding regions.

00 The maximum water injection to the field is the minimum of the field injection target, and the sum of the field production and the specified water source (the IRSRCW card). The maximum gas injection to the field is the minimum of the specified field injection target and the field available gas. The field available gas is the field production plus gaslift gas (from the previous timestep) plus makeup gas specified by the GASMKP card plus makeup gaslift gas minus the shrinkage gas minus the fuel gas minus the gaslift gas (at present timestep) minus the sales gas. If gaslift gas is not part of the gas handling loop, the gaslift gas and makeup gaslift gas are not included in the calculation.

4.7.1 Define the Injection Region Option (RINJOP)

00 The RINJOP card is used to define the injection region option to be used.

RINJOP

STD

INJREG

NODIST

REDIST

UNIFORM

PROPTN

00 Definitions:

STD Alpha label indicating that the standard reinjection option (with well management levels instead of injection regions) is to be used. This is the default.

INJREG Alpha label indicating that injection regions will be used for water and gas injection.

NODIST Alpha label indicating that the redistribution option will not be used for injection regions. This is default.

REDIST Alpha label indicating that the redistribution option will be used for injection regions.

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UNIFORM Alpha label indicating that equal amount of fluid will be distributed to each voidage controlled (FRES) well under the same region. This is default.

PROPTN Alpha label indicating that the amount of fluid distributed to each voidage controlled well in a region will be proportional to the well injectivity.

NOTE: The RINJOP INJREG card must be entered before any QMAX cards.For the INJREG option, injection wells under net voidage control and/or pressure maintenance must be specified as FRES (INJ card), but the well management level is ignored.For the INJREG option, the definition of qmax on the QMAX card is the maximum injection rate at reservoir condition when the well type is FRES.The NODIST, REDIST, UNIFORM, PROPTN options can be selected only when the INJREG option is chosen.For the REDIST option, the injection fluid available to each region is the maximum field injection rate times the percentage for the region specified in the IRPCTA card. If no percentages are input, then each injection region will be assigned the fraction, 1/(number of regions with defined voidage controlled wells). If the amount of fluid injected in a region is less than the available amount for the region, this extra amount of fluid will be redistributed to other regions according to the region’s injectivities.For the PROPTN option, the amount of fluid calculated from the voidage and pressure maintenance control is distributed to the voidage controlled wells according to the injectivities.For the UNIFORM option, the amount of fluid calculated from the voidage and pressure maintenance control is equally distributed to the voidage controlled wells.When the PERCENT option in the IRDIST card is selected, the amount of fluid calculated from the voidage and/or pressure maintenance control is neglected. Therefore, neither PROPTN nor UNIFORM option is used.

5000.4.4 4-275


00 Example 1:

00 C ***** INJECTION REGION OPTIONCRINJOP INJREG

00 Example 2:

00 ***** INJECTION REGION WITH PROPTN OPTIONCRINJOP INJREG PROPTN

4.7.2 Assign Name to Injection Region (INJRNM)

00 The INJRNM card is used to assign a name to an injection region.

INJRNM nir injrnm

00 Definitions:

nir Injection region number.

injrnm Injection region name. The first character in the name must be alphabetic unless the name is immediately preceded by the character #. Only the first eight (8) characters of the name are retained. Default is blanks.

00 Examples:

00 INJRNM 1 lNJRO1INJRNM 2 lNJRO2INJRNM 3 lNJRO3INJRNM 4 lNJRO4INJRNM 5 lNJRO5

4.7.3 Maximum Source Water Injection Rate (IRSRCW)

00 The IRSRCW card is used to specify the maximum source water injection rate available to the field, in conjunction with the injection region option.

IRSRCW irsrcw

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00 Definition:

irsrcw Maximum source water injection rate available to the field when using the injection region option, STB/D (STM3/D). Default is 0.

00 Examples:

00 C ***** SOURCE WATERCIRSRCW 1000000

4.7.4 Assign Injection Wells to Injection Regions (INJRGR)

00 The INJRGR card is used to assign appropriate injection wells to injection regions.

INJRGR wlnir1 nir2 . . . nirn

00 Definitions:

wl List of injection wells for which injection region numbers are being assigned (see Section 1.5.2).

nir Injection region number to which the well is assigned.

NOTE: The number of nir values must equal the number of wells in the well list.The INJRGR card may be omitted if the INJREGN card has been used to assign gridblocks to injection regions. In this case, wells will be assigned to the appropriate injection region based on the location of the first completion zone.If FIELD distribution data are specified on the IRDIST card, both the INJRGR and INJREGN cards maybe omitted. In this case all appropriate injection wells will be assigned to injection region number one.If any INJRGR card has been entered, the program assumes that all injectors have been explicitly assigned to regions. Thus, no injectors will be assigned automatically based on the perforation locations.

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00 Examples:

00 INJRGR 151

INJRGR 16 382*2

4.7.5 Distribution Percentage of Injection Rate to Injection Regions (IRPCTA)

00 The IRPCTA card is used to assign injection rate distribution percentages to injection regions.

IRPCTA nirpct1 pct2 . . . pctm

00 Definitions:

nir List of injection regions to which the following percentages apply. (The list nir has the same format as the well list wl.) (see Section 1.5.2)

pct Percentage to be used for appropriate distribution of injection rate to the injection regions.

NOTE: The number of pct values must equal the number of regions in the injection region list.If the percentage for a region will be required, then it should be input. If no percentages are input, then each injection region will be assigned the fraction 1/(number of areas with defined wells). The percentage for a region is required when the PERCENT option is used in the IRDIST card or when the REDIST option is selected in the RINJOP card.The sum of the percentages of all injection regions must be no greater than 100.

4.7.6 Assign Gridblocks to Injection Regions (INJREGN)

00 The INJREGN card is used to assign gridblocks to injection regions.

INJREGN nir (NOCASCADE)i1 i2 j1 j2 k1 k2 (gridname)(data card may be repeated as necessary)

00 Definitions:

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nir Injection region number to which gridblocks are being assigned.

NOCASCADE Alpha label indicating that this region number should not be cascaded to any grids located within the gridblocks defined in the data specified.

i1, i2 Gridblock range in the x direction.

j1, j2 Gridblock range in the y direction.

k1, k2 Gridblock range in the z direction.

gridname Name of the grid to which this gridblock range applies. If the gridname is not entered, the data is assumed to apply to the root grid.

NOTE: If FIELD distribution data are specified on the IRDIST card, the INJREGN card may be used to restrict which gridblocks will be used for pressure and voidage calculations (using nir = 1). In this case only injection region number one is used.INJREGN data must be input for INJREG distribution using ALL or LIQUID voidage (IRDIST card).

00 Examples:

00 C ***** INJECTION REGIONINJREGN 168 78 1 1 5 10

4.7.7 Specify How Distribution of Injection Fluid is to Occur (IRDIST)

00 The IRDIST card is used to specify how distribution of fluid is to occur in the injection regions.

IRDIST FIELD

INJREG (TYPVDG)(PRMEXP)

TRGPRSPGRAD

RFRPRSDELTAP (TYPPRS)(VDGFCT)(INFLUX)

[inum] (typvdg) (prmexp)

trgprspgrad

rfrprsdeltap (typprs)(vdgfct)

(influx)(data card may be repeated as necessary)

00 Definitions:

00 Alpha label indicating the corresponding datum on the following card(s) is:

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FIELD Field number (must be 1). This label must follow the IRDIST keyword.

INJREG Number of the injection region to which the remaining data apply. This label must follow the IRDIST keyword.

TYPVDG Type of distribution of injection rate to the injection region or the field.

PRMEXP Exponent on the pressure maintenance term.

TRGPRS Target pressure for pressure maintenance.

RFRPRS Reference pressure for pressure maintenance.

PGRAD Targeted rate of pressure decline or increase for pressure maintenance.

DELTAP Difference between reference pressure and target pressure for pressure maintenance.

TYPPRS Type of average pressure for pressure maintenance.

VDGFCT Multiplying factor to be applied to the voidage.

INFLUX Indicates that aquifer influx is to be subtracted from the voidage.

inum Field number (must be 1) or region number to which the following data apply.

typvdg Type of distribution of injection rate to the injection regions. There is no default.

ALL Voidage calculation using all three phases.

LIQUID Voidage calculation using liquid only.

PERCENT Use specified percentage(s). (IRPCTA card.)

prmexp Exponent of the pressure term. Stored value will be integer. Specify the value 0 if pressure maintenance option is not to be used. The alpha label X may be specified to maintain current value. Default is 0.

trgprs Target pressure to use for the pressure maintenance option, psia (kPa). The alpha label X may be specified to maintain current value. There is no default.

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rfrprs Reference pressure to use for the pressure maintenance option, psia (kPa). The alpha label X may be specified to maintain current value. There is no default.

pgrad Targeted rate of pressure increase/decline to use for the pressure maintenance option, psi/day (kPa/day). The alpha label X may be specified to maintain current value. There is no default.

deltap Difference between reference pressure and target pressure to use for the pressure maintenance option, psi (kPa). The alpha label X may be specified to maintain current value. There is no default.

typprs Type of average pressure to use with pressure maintenance. The alpha label X may be specified to maintain current value. There is no default.

PVWEIGHT Pore volume-weighted average.

HCWEIGHT Hydrocarbon pore volume-weighted average.

vdgfct Multiplying factor to be applied to the voidage. The alpha label X may be specified to maintain current value. Default is 1.0.

influx Indicates whether aquifer influx is to be subtracted from voidage. The alpha label X may be specified to maintain current value.

NO Do not subtract aquifer influx from voidage value. This is the default.

YES Subtract aquifer influx from voidage value.

NOTE: IRDIST FIELD data will be used only if no IRDIST INJREG data have been read.Producers to be used for voidage calculations are determined by their completion locations relative to the injection region gridblock assignments. If a producer is completed in more than one region, the actual production from the completions in each region will be used to determine voidage for each region.If FIELD distribution is input, but no INJREGN cards have been input, then the entire field is treated as the injection region. If INJRGR cards have also been omitted, all appropriate injection wells are assigned to injection region one.For the injection rate distribution type typvdg:

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ALL or LIQUID must be specified for pressure maintenance.When ALL or LIQUID are used with FIELD, the field injection rate at reservoir conditions is then allocated to the injection regions using percentages.

When PERCENT is used with FIELD, the field injection rate at surface conditions (the minimum of the field production rate plus the injection source and the specified field injection target) is then allocated to the injection regions using percentages.The reference pressure rfrprs must exceed both the target pressure trgprs and the computed average pressure.The pairs of data rfrprs/trgprs and pgrad/deltap may not occur on the same IRDIST card. These options are mutually exclusive.

00 Examples:

00 CIRDIST INJREG TYPVDG VDGFCT INFLUX 1 ALL 1.0 NO

4.7.8 Forced Gas Injection Into Injection Regions (IRGAS)

00 The IRGAS card is used to activate the forced gas injection option, in conjunction

with the injection region option, and to define the and parameters for the forced gas regions.

IRGAS nir or IRGAS OFFON

alpha1 alpha2 ... alphambeta1 beta2 ... betam

00 Definitions:

nir List of injection regions to which the following and parameters apply. (The list nir has the same format as the well list wl.) (see Section 1.5.2)

OFF Alpha label indicating that the forced gas injection option is now inactive. The alpha and beta parameters will be retained in case the option is ever reactivated.

ON Alpha label indicating that the forced gas injection option is to be reactivated.

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alpha parameter for a forced gas region. See Notes for an explanation of its usage.

beta parameter for a forced gas region. See Notes for an explanation of its usage.

NOTE: The number of alpha and beta values must equal the number of regions in the injection region list.

The values of alpha and beta must lie between 0. and 1., inclusive.

The sum of the beta values over all forced gas regions must be 1.

Wells defined as forced gas injectors inject gas even if pressure maintenance criteria are violated. Such an option is useful when the flaring of excess produced gas is not allowed.

Under the forced gas option (IRGAS card specified), the forced gas injectors are those gas injectors for which FRES is specified on the INJ card. FRES gas injectors may only exist in forced gas regions; i.e., those for which ’s and ’s are specified. No FRES gas injector may exist in a non-forced gas region.

The injection gas rate is distributed to the injection regions as follows:

Define:

R entire reservoir

F forced gas regions

parameter for each forced gas region

parameter for each forced gas region

qGI well gas injection rate for non-FRES wells

QGI non-FRES injection rate in each region, =qGI

QGI total gas injection rate in each region

QGP total gas production rate from each region

QGPFnet

net field gas production rate

QGP i sales fuel shrinkage+ + – makeup+iR

QRINJ gas production rate minus non-FRES gas injection rate

QGPFnet

QGI i iR

–

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For each non-forced gas injection region k,

QGI k QGI k =

For each forced gas injection region i,

QGI i i QGP i

j QGP j jF

-------------------------------------- min j QGP j QRINJ

jF

=

+ i QRINJ min j QGP j QRINJjF

–

QGI i +

Note that in all cases

QGI i iR

QGPFnet

=

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4.7.9 Select Gas Project Prioritization Option (PRIOP)

00 The PRIOP card is used to activate the gas prioritization option within the general injection region option. The INJREG label must have been input on the RINJOP card to use this option.

PRIOP

ON

OFF

00 Definitions:

ON Alpha label indicating that the gas prioritization option will be used.

OFF Alpha label indicating that the gas prioritization option is not used. This is the default.

00 Examples:

00 C ***** GAS PRIORITIZATION OPTIONCPRIOP ON

4.7.10 Assign Name to Gas Project (PROJNM)

00 The PROJNM card is used to assign a name to a gas project.

PROJNM nproj projnm

00 Definitions:

nproj Project number.

projnm Project name. The first character in the name must be alphabetic unless the name is immediately preceded by the character #. Only the first eight (8) characters of the name are retained. Default is blanks.

00 Examples:

00 C ***** NAME OF THE GAS PROJECT

00 CPROJNM 1 MGIPROJNM 2 IMGIPROJNM 3 GS

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4.7.11 Assign Gas Injection Wells to Projects (PROJWL)

00 The PROJWL card is used to assign the appropriate gas injection wells to the projects.

PROJWL wlnproj1 nproj2 . . . nprojn

00 Definitions:

wl List of gas injection wells for which projects are being assigned (see Section 1.5.2).

nproj Project number to which the well is assigned.

NOTE: The number of nproj values must equal the number of wells in the well list.Only a gas injection well can be assigned to a project. The FRES well type in the injection region option is a net voidage injection well. Since water injection follows gas injection in the prioritization option, the user cannot specify FRES gas injection wells in the option.

00 Examples:

00 C ASSIGN GAS INJECTORS TO PROJECTS PROJWL 1 -41 2 1 2

4.7.12 Prioritize Gas Projects (PRIIR)

00 The PRIIR card is used to prioritize gas projects in injection regions. If a priority is to be skipped in an injection region, the user should specify project 0 for that priority.

PRIIR

INJREG

FIELDirl

nproj1 nproj2 ... nprojn

00 Definitions:

INJREG Injection region option is used to prioritize the projects.

FIELD Field option is used to prioritize the projects.

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irl List of injection regions to which prioritization is being assigned (the injection region list irl has the same format as the well list wl). (see Section 1.5.2)

nprojn Assign a project number to priority n.

00 Examples:

00 C ***** PRIORITIZE PROJECTSCPRIIR INJREG 1 -31 3 4 2 5PRIIR INJREG 41 0 3 4 5

4.8 Voidage Injection by Guide Rate (Not available in VIP-THERM)

00 A guide rate voidage injection scheme has been implemented in VIP-EXECUTIVE. The INJ and the QMAX cards are modified when the new scheme is used. The FRES and FSTD options define the wells under new voidage replacement control. The GATHER, FLOSTA, AREA, and FIELD option on the INJ card indicates the well management level upon which the gas injection composition is based. The QMAX card specifies the maximum injection rate even though the well type is FRES or FSTD.

00 Two input option cards, INJTAR and INJGR, are added. The INJTAR card specifies the injection target and the INJGR card specifies the guide rate.

00 Note that any additional injection rate data (INJA) is ignored when this option is used.

4.8.1 Maximum Injection Target for a Group (INJTAR)

00 The INJTAR card is used to specify the maximum injection target for a group.

INJTAR

GATHER

FLOSTA

AREA

FIELD

inum W

G

RSTD

RRES

FSTD

FRES

FRESN

OFF

qtarg

00 Definitions:

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00 Alpha label indicating the level of the well management hierarchy to which the maximum injection rate applies:


FLOSTA Flow Station.

AREA Area.

FIELD Field.


W Water injection.

G Gas injection.

RSTD Rate specified is at surface condition, STB/D (STM3/D) for water and MSCF/D (SM3/D) for gas.

RRES Rate specified is at reservoir condition, RB/D (M3/D).

FSTD Rate specified is a fraction of the phase production rate.

FRES Rate specified is a fraction of total voidage.

FRESN Rate specified is a fraction of net voidage.

OFF This keyword turns voidage injection by guide rate off for all injection wells of this type (W or G). All injectors of this type should be respecified for proper operation.

qtarg The maximum injection rate if either the RSTD or RRES option is used. The fraction of the production rate if either the FSTD, FRES, or FRESN option is used.

NOTE: If the RSTD or FSTD option is used, then the well should be defined with the FSTD option on the INJ card. If the RRES, FRES, or FRESN option is used, then the well should be defined with the FRES option on the INJ card.One and only one of the GATHER, FLOSTA, AREA, or FIELD labels must be specified. There is no default. When FIELD is specified the inum entry may be omitted, or the value 1 may be input; no other value will be accepted.One and only one of the W or G labels must be specified. There is no default. One and only one of the RSTD, RRES, FSTD, FRES, or FRESN labels must be specified. There is no default.

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The QMAX card specifies the maximum injection rate even though the well type is FRES or FSTD.

4.8.2 Injection Guide Rate for a Group (INJGR)

00 The INJGR card is used to specify the injection guide rate for a group.

INJGR

WELL

GATHER

FLOSTA

AREA

inum W

G

GURTS grate

GURTR grate

VOID

VOIN

00 Definitions:

00 Alpha label indicating the level of the well management hierarchy to which the injection guide rate applies:

WELL Well.



AREA Area.


W Water injection.

G Gas injection

GURTS Guide rate in surface units will be input, STB/D or MSCF/D (STM3/D or SM3/D).

GURTR Guide rate in reservoir units will be input, rb/D (rm3/D).

VOID Guide rate is set to voidage.

VOIN Guide rate is set to net voidage.

grate Guide rate for GURTS and GURTR options.

NOTE: If the VOID or VOIN option is used, then the guide rate need not be specified and will be ignored if it is input.

5000.4.4 4-289


For WELL, only the GURTS or GURTR option can be chosen.One and only one of the WELL, GATHER, FLOSTA, or AREA labels must be specified. There is no default. One and only one of the W or G labels must be specified. There is no default. One and only one of the GURTS, GURTR, VOID, or VOIN labels must be specified. There is no default.

4.9 Water Injection Pumps (Not available in VIP-THERM)

00 Groups of water injectors are commonly controlled by the same pump system, especially in offshore situations, where a large number of injectors are often driven from one pump system on an offshore platform. The discharge pressures of these pump systems vary (usually decreasing) with flow rate delivered, so it is inappropriate to assume that water injectors coupled to such a pump system operate at a constant tubinghead pressure independent of the total flow rate delivered by the pump system.

00 Water injectors connected to a common injection pump system can be modeled accurately in VIP-EXECUTIVE by using the water injector pump system option. Injectors connected to a common pump system must be defined within the same gathering center. This gathering center is then assigned to a table of pump discharge pressure (thp) versus flow rate using the IPUMP card. Finally the pump characteristics may be defined using the PMPTAB card. The user may define multiple pump tables and assign more than one gathering center to the same pump table in much the same way that bottomhole pressure tables are now used.

4.9.1 Assign Injector Pump Characteristics Tables (IPUMP)

00 IPUMP data must be defined along with PMPTAB data if gathering center water injectors are to be controlled by pump characteristics tables.

00 The IPUMP card allows the user to assign a table of water injector pump characteristics to the water injectors in a gathering center.

IPUMP gl ipmp1 ipmp2 . . . ipmpn

00 Definitions:

gl List of gathering centers for which the ipmp values are being entered. (The gathering center list gl has the same format as well lists wl). (see Section 1.5.2)

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ipmp Number of the pump table (PMPTAB card) that defines the pump characteristics for this gathering center.

NOTE: The number of ipmp values must equal the number of gathering centers in the gathering center list.

4.9.2 Water Injection Pump Discharge Pressure (PMPTAB)

00 A PMPTAB card must be defined if an IPUMP card is entered for a gathering center.

00 PMPTAB data are used to relate a water injection pump discharge pressure (tubinghead pressure) to the flow rate delivered by the pump.

PMPTAB npmpQPMP THPq1 thp1. .. .. .qn thpn

00 Definitions:

npmp Number of the pump table being read.

QPMP Alpha label indicating that this column contains pump flow rates.

THP Alpha label indicating that this column contains pump discharge pressures.

q Pump flow rates, STB/D (STM3/D).

thp Pump discharge pressures, psia (kPa).

NOTE: 1. The number of pump flow rates and pump discharge pressure values must be less than or equal to NPMPV (see DIM data).

2. The total number of pump tables must be less than or equal to NPMPMX (see DIM data).

4.9.3 Convergence Criteria (WTRPUMP)

00 The WTRPUMP card allows the user to set the convergence criteria for the water

5000.4.4 4-291


injection pump algorithm.

WTRPUMP itnpmp pmptol

00 Definitions:

itnpmp Maximum number of pump pressure iterations. Default is 10.

pmptol Rate tolerance for convergence of the pump pressure iterations, STB/D (STM3/D). Default is 10 STB/D.

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4.10 Gaslift

00 To invoke gaslift, THP data must also be defined.

4.10.1 Gaslift Allocation (QLIFT)

00 A QLIFT card is used to explicitly place a well on gaslift, to take a well off gaslift, or to explicitly allocate the amount of lift gas going to the well.

QLIFT wl qlift1 qlift2 . . . qliftn

00 Definitions:

wl List of production wells for which qlift values are being specified (see Section 1.5.2).

qlift The rate, MSCF/D (SM3/D), at which lift gas is injected into a production well:

A positive value causes a constant allocation of lift gas to the well.

A zero value takes the well off gas lift.

A negative value causes invocation of an automatic allocation procedure for the well. (See QLIFTA card)

NOTE: 1. The number of qlift values must equal the number of wells in the well list.

2. If a well is on gaslift, one of the following indicators appears in the GAS LIFT STATUS column of the production well summary:

SPEC Specified, a positive qlift value has been supplied.

GLRTAB Optimal GLR table used to allocate lift gas rate; a negative qlift value has been supplied.

PFMCRV Performance curve algorithm used to allocate lift gas rate; a negative qlift value has been supplied.

*VLE Gaslift removed from well due to violation of minimum gaslift efficiency constraint GLEFMN.

5000.4.4 4-293


*GLE Gaslift removed from well based on lift efficiency when a gaslift gas shortage occurs; a negative qlift value has been supplied.

*WCT Gaslift removed from well based on water-cut when a gaslift gas shortage occurs; rate originally calculated using optimum LGR table.

*SCL Gaslift gas rate scaled back due to a gaslift gas shortage; a negative qlift value has been supplied.

*HIT Gaslift gas removed from well that was designated on the PFMCRV option hit list.

GLRMIN Gaslift gas rate reduced to honor the specified glr minimum; rate originally calculated using the PFMCRV algorithm.

GLRMAX Gaslift gas rate reduced to honor the specified glr maximum; rate originally calculated using the PFMCRV algorithm.

3. The gaslift rate is used by the program only to determine the flowing bottomhole pressure which corresponds to the user-specified tubinghead pressure limit. Gaslift is otherwise transparent to the user; i.e., the gaslift rate is NOT included in daily gas production. Gaslift can be used only on wells for which a THP card is entered.

4-294 5000.4.4


4.10.2 Gaslift Gas Source (QLIFTA)

00 To invoke automatic gaslift for a well, a QLIFT card with a negative value must be defined.

00 A QLIFTA card is used to specify the amount of available gaslift gas for automatic allocation, the allocation method and the fraction of produced gas also available as gaslift gas. The source of available gaslift gas is not

00 specified, merely its volume. The data are order dependent. If an item is left off it is set to its default value, overriding any previously input value.

QLIFTA

GATHER

FLOSTA

AREA

FIELD

inum qlifta

OPTTAB

TABGLE

TABWC

TABSCL

PFMCRV

ALLWLS

LFTWLS

(gasfct)

00 Definitions:

00 Alpha label indicating the level of the well management hierarchy to which the specified gaslift gas data apply:



AREA Area.

FIELD Field.


qlifta Amount of gaslift gas per day available for injection into all of the production wells which are on automatic allocation of gaslift gas, MSCF/D (SM3/D).

OPTTAB Alpha label indicating that optimal GLR tables are to be used to compute the gaslift gas injection rate for each well on automatic allocation of gaslift gas. (See GLRTAB card)

TABGLE Alpha label indicating that wells will be shut in based on gaslift efficiency when a gaslift shortage exists. The

5000.4.4 4-295


gaslift gas injection rates are computed using the optimal GLR tables.

TABWC Alpha label indicating that wells will be shut in based on water cut when a gaslift shortage exists. The gaslift gas injection rates are computed using the optimal GLR tables.

TABSCL Alpha label indicating that gaslift gas injection rates will be scaled back when a gaslift shortage exists. The gaslift gas injection rates are computed using the optimal GLR tables.

PFMCRV Alpha label indicating that the performance curve option is to be used to calculate gaslift gas rates.

ALLWLS Alpha label causing a fraction of the gas produced from this member of the well management hierarchy during one timestep to be used as additional gaslift gas during the next timestep. This is the default.

LFTWLS Alpha label causing a fraction of the gas produced from only those wells in this member of the well management hierarchy on gaslift during one timestep to be used as additional gaslift gas during the next timestep.

gasfct Fraction of the produced gas to be used as gaslift gas. Default is zero.


2. Gaslift gas is automatically allocated among those wells for which a negative qlift value was entered on a QLIFT card.

3. The gaslift gas calculation using the optimal GLR tables is done during the first outer iteration of each timestep. The calculated gaslift gas rate is used for subsequent iterations.

4. For each well on automatic allocation, the gaslift gas rate is checked against the allowable maximum defined on the GLGMAX card. If a violation occurs the rate is reset to the maximum.

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4.10.3 Optimal GLR Tables for Gaslift (GLRTAB)

00 GLRTAB data are used to relate gas-liquid (or gas-oil) ratio to flow rate and water cut (and possibly pressure) for the computation of gaslift gas rates. More than one well can refer to the same GLRTAB.

GLRTAB nglrQLIQ

QOq1 q2 . . . qk

WCUT wcut1 (wcut2 . . . wcutl)(PRESSURE pres1 (pres2 . . . presm))IWCUT

IQLIQ

IQO(IPRES) GLR

GOR

iwcut1 iq1 (ip1) glr1. . . .. . . .. . . .iwcutl iqk (ipm) glrlkm

00 Definitions:

nglr Number of the optimal GLR table being read.

QLIQ Alpha label indicating that values on this card are liquid rates (oil plus water). This must be used with GLR.

QO Alpha label indicating that values on this card are oil rates. This must be used with GOR.

q Liquid or oil rates, STB/D (STM3/D). Values can be unequally spaced.

WCUT Alpha label indicating that water-cut values are read on this card.

wcut Water-cut values, fraction. Values can be unequally spaced.

PRESSURE Alpha label indicating that pressure values are read on this card. This card is optional.


5000.4.4 4-297


IWCUT Alpha label indicating that the values read in the column under this heading are water-cut indices.

IQLIQ Alpha label indicating that the values read in the column under this heading are liquid rate indices. This must be used with QLIQ.

IQO Alpha label indicating that the values read in the column under this heading are oil rate indices. This must be used with QO.

IPRES Alpha label indicating that the values read in the column under this heading are pressure indices. This label can be included only if a PRESSURE card was input.

GLR Alpha label indicating that the values read in the column under this heading are gas-liquid ratios. This must be used with QLIQ.

GOR Alpha label indicating that the values read in the column under this heading are gas-oil ratios. This must be used with QO.

iwcutl Index referring to the l-th water-cut value read.

ipm Index referring to the m-th pressure value read. This index can be included only if a PRESSURE card was input.

iqk Index referring to the k-th rate value read.

glrlkm The gas-liquid (gas-oil) ratio value corresponding to the indicated water-cut, rate, and pressure values, SCF/STB (SM3/STM3).

4.10.4 Optimal GLR Table Pointer for Gaslift (GLRTBP)

00 This card is used in conjunction with the GLRTAB card.

00 A GLRTBP card is used to specify the optimal GLR table to which a well on automatic allocation of gaslift gas points.

GLRTBP wl iglrtb1 iglrtb2 . . . iglrtbn

00 Definitions:

wl List of production wells for which iglrtb values are being specified (see Section 1.5.2).

4-298 5000.4.4


iglrtb The number of the optimal GLR table (GLRTAB card) that defines the gas-liquid ratio, including lift gas, for this well.

NOTE: 1. The number of iglrtb values must equal the number of wells in the well list.

2. If an iglrtb value has not been specified for a well, the GLR table pointer value used will be the same as the BHP table pointer input on the ITUBE card.

4.10.5 Maximum Well Gaslift Gas Rate (GLGMAX)

00 A GLGMAX card is used to limit the gaslift gas rate for a well whose lift rate is allocated automatically.

00 GLGMAX Card for WELLS

GLGMAX WELL wlglgmax1 glgmax2 . . . glgmaxn

00 GLGMAX card for WELL MANAGEMENT LEVELS

GLGMAX

GATHER

FLOSTA

AREA

FIELD

inum glgmax

00 Definitions for wells:

wl List of wells for which maximum gaslift gas rates are being specified (see Section 1.5.2).

glgmax Maximum gaslift gas rate for the well MSCF/D (SM3/D).

00 Definitions for well management levels:

Alpha label indicating the level of the well management hierarchy to which the specified maximum gaslift gas rate applies:



5000.4.4 4-299


AREA Area.

FIELD Field.


glgmax Maximum gaslift gas rate, MSCF/D (SM3/D). Default is 0.

NOTE: 1. If GLGMAX is specified at the well level, the number of glgmax values must equal the number of wells in the well list.

2. If GLGMAX is specified by well management level, one and only one of the GATHER, FLOSTA, AREA, or FIELD labels must be specified. There is no default. When FIELD is specified the inum entry may be omitted, or the value 1 may be input; no other value will be accepted.

3. Only wells on automatic allocation of lift gas are checked against the maximum.

4.10.6 Minimum Well Gaslift Gas Rate (GLGMIN)

00 A GLGMIN card is used to limit the gaslift gas rate for a well whose lift rate is allocated automatically.

00 GLGMIN Card for WELLS

GLGMIN WELL wlglgmin1 glgmin2 . . . glgminn

00 GLGMIN card for WELL MANAGEMENT LEVELS

GLGMIN

GATHER

FLOSTA

AREA

FIELD

inum glgmin

00 Definitions for wells:

wl List of wells for which minimum gaslift gas rates are being specified (see Section 1.5.2).

glgmin Minimum gaslift gas rate for the well MSCF/D (SM3/D).

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00 Definitions for well management levels:

Alpha label indicating the level of the well management hierarchy to which the specified minimum gaslift gas rate applies:



AREA Area.

FIELD Field.


glgmax Maximum gaslift gas rate, MSCF/D (SM3/D). Default is 0.

NOTE: 1. If GLGMIN is specified at the well level, the number of glgmin values must equal the number of wells in the well list.

2. If GLGMIN is specified by well management level, one and only one of the GATHER, FLOSTA, AREA, or FIELD labels must be specified. There is no default. When FIELD is specified the inum entry may be omitted, or the value 1 may be input; no other value will be accepted.

3. Only wells on automatic allocation of lift gas are checked against the minimum.

4.10.7 Additive Correction to GLR Tables (GLRADD)

00 This card is used in conjunction with the GLRTAB card.

00 The GLRADD card is used to provide an additive correction term to the value of gas-liquid (or gas-oil) ratio obtained from the optimal GLR tables.

GLRADD wl glradd1 glradd2. . . glraddn

00 Definitions:

wl List of production wells for which glradd values are being specified (see Section 1.5.2).

glradd Additive correction to apply to the value of gas-liquid (or gas-oil) ratio obtained from the optimal GLR tables for

5000.4.4 4-301


the well, SCF/STB (SM3/STM3). Value may be positive or negative. Default is 0.0 SCF/STB.

NOTE: The number of glradd values must equal the number of wells in the well list.

4.10.8 Time Interval for Gaslift Gas Rate Calculations (TESTGL)

00 The TESTGL card is used to specify the time interval between gaslift gas rate calculations for automatic allocation of gaslift gas.

TESTGL tincg

00 Definition:

tincg Time interval between gaslift gas rate calculations for automatic allocation of gaslift gas, days. Default is 0 days, causing calculations every timestep.

NOTE: The calculations are scheduled for the time at which the TESTGL card is read plus tincg days. Until the simulation reaches that time, no calculations will be performed. Timesteps are not adjusted to hit the time exactly. Once the calculations are done, the new scheduled time will be tincg days farther into the simulation.

4.10.9 Minimum Gaslift Efficiency (GLEFMN)

00 The GLEFMN card is used to specify a minimum gaslift efficiency to test against each well on gaslift.

GLEFMN glefmn

00 Definition:

glefmn Minimum gaslift efficiency, STB/MMSCF (STM3/KSM3); if the gaslift efficiency of a well, calculated as oil production rate/gaslift gas rate, drops below glefmn, the well will be taken off gaslift.

4.10.10 Performance Curve Option Data (PFMCRV)

00 The PFMCRV option enables the user to calculate gaslift gas rates based on the lift efficiencies of the wells, where lift efficiency is defined as the incremental oil

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produced (STB/D) per increment of gaslift gas (MMSCF/D).

PFMCRV(GLRMIN glrmin)(GLRMAX glrmax)(LIFTEFF eff)(MAXSCALE scale)(GLDAMP gldamp)EFFSCL ON

OFFWARNING

TOTGAS ON

OFF

(HITLIST wl) WGLRMIN wl

wglr1 wglr2 wglrn

OUTFILETIME

TNEXT

OFF

(freq)

00

00 Definitions:

glrmin Minimum gas-liquid ratio with which to compare the gas-liquid ratio at the performance curve operating points, SCF/STB (SM3/STM3). The well’s gaslift gas rate will be reset to honor this minimum. Default is 0.

glrmax Maximum gas-liquid ratio with which to compare the gas-liquid ratio at the performance curve operating points, SCF/STB (SM3/STM3). The well’s gaslift gas rate will be reset to honor this maximum. Default is 1.E10.

eff Desired lift efficiency of the allocated gaslift gas rate (i.e., the slope of the performance curve at the optimal operating point), STB/MMSCF (STM3/KSM3). Default is 10 STB/MMSCF.

scale Maximum scaleback factor to use in the algorithm for reducing gaslift gas rates to meet target, fraction.

gldamp Damping factor a used in the SP gaslift optimization algorithm of the Surface Pipeline Network option

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(Section 10.19.9), fraction. Default is 0. Value must be between 0. and 1., inclusive.

EFFSCL Alpha label indicating whether the uniform lift efficiency scaleup option is to be used.

ON Keyword indicating the option is on.

OFF Keyword indicating the option is off. This is the default.

WARNING Alpha label indicating that non-convergence warning messages generated by this option should be printed. Default is to not print them.

TOTGAS Alpha label indicating how lift efficiency is to be calculated.

ON Keyword indicating lift efficiency is to be calculated as a function of total gas (produced gas plus gaslift gas).

OFF Keyword indicating lift efficiency is to be calculated as a function of gaslift gas. This is the default.

HITLIST Alpha label indicating that the specified wells on this card are to have their gaslift gas rates removed when the total allocated lift rate exceeds the available lift gas.

wl List of wells on the hit list - each well must be named, ranges of wells will not be accepted.

WGLRMIN Alpha label indicating that the following data are minimum gas-liquid ratios below which the wells are not to be reduced during the scale-back step of reducing gaslift gas rates.

wl List of wells for which gas-liquid ratio values are being specified (see Section 1.5.2).

wglr Minimum gas-liquid ratios, SCF/STB (SM3/ STM3). Default is 0.

OUTFILE Alpha label indicating that for the gaslift gas optimization option (Section 4.11) performance curve data for each well is to be written to the file named <casename>_pfmcrv.out.

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TIME Alpha label that causes the file to be written each time the DATE or TIME card is encountered.

TNEXT Alpha label that causes the file to be written only the next time a DATE or TIME card is encountered.

OFF Alpha label that causes the file not to be written. This is the default.

freq A number that causes the file to be written after every freq timestep (each timestep cut counts as a timestep).

NOTE: Usage of this option requires that the BHPTAB wellbore hydraulics tables have been input with a sufficient range to cover all of the oil, water, and total gas (produced reservoir gas plus gaslift gas) rates that may be encountered with the gaslift calculations. It should be noted that the wellbore hydraulics algorithm will extrapolate outside of the table range, if necessary. Warning messages are printed for table extrapolations. This feature provides the user with a mechanism for determining gaslift gas allocation without having to generate optional gas-liquid/gas-oil ratio tables. An internal table is generated and user-supplied data determines the point at which the gaslift gas rate is found.The data related to the HITLIST, MAXSCALE and WGLRMIN keywords is ignored when the EFFSCL option is turned on.When WGLRMIN data is entered, the number of gas-liquid ratio values must equal the number of wells in the well list.

4.10.11 Gaslift Gas in Gas Handling Loop (GLGOP)

00 The GLGOP card is used to assign the gaslift gas as part of the gas handling loop.

GLGOP

OPEN

CLOSE

00 Definitions:

OPEN Gaslift gas in part of the gas handling loop.

CLOSE Gaslift gas is not included in the gas handling loop. This is the default.

00 Reinjection volumes are calculated based on the sum of produced and gaslift gas. At any given time, the amount of gas in the loop will be:

5000.4.4 4-305


00 [produced + makeup - shrinkage - fuel + previous gas lift + makeup gas lift = sales + injection + current gas lift]

00 Examples:

00 C ***** GASLIFT GAS IS PART OF THE GAS HANDLING LOOPCGLGOP OPEN

4.10.12 Makeup Gaslift Gas Specification (QLIFTM)

00 The QLIFTM card is used to specify the makeup gaslift gas rate, when gaslift gas is part of the gas handling loop (GLGOP OPEN).

QLIFTM

GATHER

FLOSTA

AREA

FIELD

inum qrate (frate)

00 Definitions:

00 Alpha label indicating the level of well management hierarchy to which the makeup gaslift gas rate applies:



AREA Area.

FIELD Field.


qrate Makeup gaslift gas rate, MSCF/D (SM3/D).

frate Fraction of the surface production rate.

NOTE: If both qrate and frate are specified, the makeup gaslift gas rate is the specified rate plus the fraction of the surface production rate. (qrate + frate * the surface production rate).

00 Examples:

00 C ***** MAKEUP GASLIFT GAS RATE

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QLIFTM GATHER 1 100. 0.1QLIFTM GATHER 2 50.

4.11 Multi-level Optimization of Gaslift Gas Utilization

4.11.1 Introduction

00 The primary function of this algorithm is to optimize (i.e., minimize) the gaslift gas required to meet the specified oil targets at any specified group level. It can only be used for oil phase targets. The optimization is performed by finding the maximum common gaslift gas operating efficiency at which the target rate can be met.

4.11.2 Specifications

00 There are several specifications required to invoke the optimization. These are:

n QLIFTA (Section 4.10.2) data specifying PFMCRV for each level at which the optimization is requested.

n PTARG (Section 4.3.1) data specifying an O (oil) target for the level.

n TRGOPT (Section 4.3.4) data, for phase O, specifying the SCALE option for reduction of the oil rate to meet the target. This is the default if no TRGOPT data for phase O is input.

n PFMCRV (Section 4.10.10) data introduced, including the optional OUTFILE label.

n EFFSCL (Section 4.10.10) efficiency scaling specified.

n One or more wells on automatic gaslift gas allocation, (see QLIFT, Section 4.10.1).

00 For each well on automatic gaslift gas allocation using the performance curve option, a performance curve is constructed at the start of each specified Newton iteration, describing the relationship of oil production rate versus gaslift gas utilized. These curves will be used in the optimization algorithm to determine the maximum common operating efficiency (minimum total gaslift gas requirement) required to meet the oil target. No gaslift gas will be used if the target can be met without any gaslift gas.

00 In order to have smooth and continuous relationships for the gaslift performance for the wells, a multi-segmented second-order curve fit is employed for the function of oil rate versus the log of gaslift gas rate. The derivative of this function is then used to determine the current operating efficiency at any gaslift gas rate within the interval.

5000.4.4 4-307


4.11.3 Gaslift Optimization Outer Iteration Number (ITNGLG)

ITNGLG nitglg

nitglg Maximum number of iterations per timestep at which to perform the gaslift gas optimization algorithm. Default is 1.

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4.12 Automatic Drilling Option

00 The parameter NRIGTOT must be greater than zero on the DIM card to activate the automatic drilling option.

00 The total number of rigs defined by all DRLRIG and WRKRIG cards may not exceed the dimension NRIGTOT.

4.12.1 Drilling Rig Definition (DRLRIG)

00 The DRLRIG card is used to define the drilling rigs available at any well management level and all levels below it. Rigs can be added or removed at any time.

DRLRIG

GATHER

FLOSTA

AREA

FIELD

inum

ADD

REPLACE

SUBTRACT

irigs

ALL (wktim) (mvtim)

00 Definitions:

Alpha label indicating the level of the well management hierarchy to which the specified rig is available:



AREA Area.

FIELD Field.


ADD Alpha label indicating irigs rigs should be added to the number of rigs available.

REPLACE Alpha label indicating the rigs specified should replace any previously specified rigs for this member of well management.

SUBTRACT Alpha label indicating irigs rigs should be subtracted.

irigs Number of rigs.

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ALL Alpha label indicating all rigs currently assigned are to be subtracted.

wktim Time required to complete a workover, days. Default is 0.

mvtim Time required to move a rig, days. Default is 0.

NOTE: 1. ALL can be used only with SUBTRACT. If irigs is used to subtract rigs, they are subtracted from the bottom of the list.

2. One and only one of the GATHER, FLOSTA, AREA, or FIELD labels must be specified. There is no default. When FIELD is specified the inum entry may be omitted, or the value 1 may be input; no other value will be accepted.

4.12.2 List of Wells in Drilling Queues (DRILLQUEUE)

00 The DRILLQUEUE card is used to define sets of wells to be drilled in the automatic drilling option, either automatically based on rig availability or when specified group targets cannot be met.

DRILLQUEUE nNEW

APPENDOFF

AUTONORIGS

(name)

GROUP

GATHERFLOSTAAREAFIELDINJREG

ALL

list

. . . GROUP . . .

TARGETS [targets] POTENTIAL [phase] (thrate)

00 wlqmax1 qmax2 ... qmaxn

00 Definitions:

n Drilling queue number. This is required.

NEW Alpha label indicating that this data replaces any previously specified data for this drilling queue. This is

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the default if none of the labels NEW, APPEND, or OFF is entered.

APPEND Alpha label indicating that this data is in addition to any previously specified data for this drilling queue.

OFF Alpha label indicating that this drilling queue no longer exists. All previously entered data for this queue is erased. No data (GROUP, TARGETS, POTENTIAL, well list or qmax) may be entered after the DRILLQUEUE card.

AUTO Alpha label indicating that this drilling queue is not subject to any conditions. The wells will be drilled in the order specified as long as rigs are available. Only one drilling queue may be designated as AUTO; a previously designated AUTO drilling queue will lose that designation.

NORIGS Alpha label indicating that wells are to be drilled from this queue independent of rig availability. This applies only for the targeting option; NORIGS may not be specified for the AUTO queue.

name Drilling queue name. This should only be entered when a new queue is being defined. It will be ignored if APPEND is specified for a queue with previously entered data.

GROUP This record is used to define the members of the well management hierarchy that will be checked for not meeting targets. If one or more of the targets is not met, the next available well in the well list will be drilled. The well management hierarchy levels are:

GATHER Gathering centerFLOSTA Flow stationAREA AreaFIELD FieldINJREG Injection region

Note that multiple GROUP cards can be entered.

ALL Alpha label indicating that all the members of this level are to be included.

list One or more names or numbers of members of this level to be included. This may be left blank, or the number 1 must be specified, if FIELD is entered.

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TARGETS This record is used to define which production targets (PTARG) or injection targets (ITARG) are to be checked for the drilling option. Production and injection targets may not both be specified for a queue. Also, only injection targets may be specified if the INJREG group is entered for this queue.

The rates used to compare against targets are the sums of the well rates before possible reductions due to surface network constraints and/or targeting. See DRLTRG card for the specification of the targets against which the rates are compared.

One or more of the following may be entered on the TARGETS card:

OILPROD Oil production targetLIQPROD Liquid production targetGASPROD Gas production targetWATPROD Water production targetGASINJ Gas injection targetWATINJ Water injection target

POTENTIAL This record is used to designate that, when the next available well in the queue is to be determined, the eligible well with the greatest flow potential is chosen. One of the following may be entered for phase on the POTENTIAL card:

OILPROD Oil productionLIQPROD Liquid productionGASPROD Gas productionWATPROD Water productionGASINJ Gas injectionWATINJ Water injection

thrate Threshold rate above which a well must flow to be a drilling candidate with the POTENTIAL option. Units: STB/D (STM3/D) for oil, water, liquid, and MSCF/D (KSM3/D) for gas. Default is 0.

wl List of wells in this drilling queue. All data necessary for each of these wells is assumed to have been entered by the time the well is drilled. The rate type MULTRT is not allowed for a well in a drill queue.

qmax Maximum production/injection rate for each well to be drilled. The units of this rate depend on the well type (see QMAX card).

00

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00 Example:

00 DRILLQUEUE 2GROUP GATHER 1 3GROUP FLOSTA 4TARGETS OILPROD GASPROD10 11 13 -15 12 207*1500

4.12.3 Target Specification (DRLTRG)

00 The DRLTRG card is used to specify the how the target used in the DRILLQUEUE algorithm is to be computed.

00 If a DRLTRG card is not entered for a target type specified in the DRILLQUEUE data, the target rate checked will default to 1.2 times the appropriate production/injection target.

DRLTRG

GATHERFLOSTAAREAFIELDINJREG

inum

GPROD

OPROD

WPROD

LPROD

GINJ

WINJ

drltrg MULT

INCR

RATE

00 Definitions:

Alpha label indicating the level of the well management hierarchy to which the specified data applies:



AREA Area.

FIELD Field.

INJREG Injection Region.


5000.4.4 4-313


GPROD Alpha label indicating that the data on this card applies to gas production target specified on the DRILLQUEUE card.

OPROD Alpha label indicating that the data on this card applies to oil production target specified on the DRILLQUEUE card.

WPROD Alpha label indicating that the data on this card applies to water production target specified on the DRILLQUEUE card.

LPROD Alpha label indicating that the data on this card applies to liquid production target specified on the DRILLQUEUE card.

GINJ Alpha label indicating that the data on this card applies to gas injection target specified on the DRILLQUEUE card.

WINJ Alpha label indicating that the data on this card applies to water injection target specified on the DRILLQUEUE card.

drltrg Value used to compute the target rate to be checked; definition depends on input of MULT, INCR, or RATE. Units: for MULT, drltrg is a multiplier; for INCR and RATE, unit is STB/D (STM3/D) for oil, water, liquid, and is MSCF/D (KSM3/D) for gas.

MULT Alpha label indicating that the target rate to be checked is drltrg times the appropriate production/injection target.

INCR Alpha label indicating that the target rate to be checked is the sum of drltrg and the appropriate production/injection target.

RATE Alpha label indicating that the target rate to be checked is drltrg.

NOTE: 1. The only data not required is inum if FIELD is entered. When FIELD is specified the inum entry may be omitted, or the value 1 may be input; no other value will be accepted.

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4.12.4 Drilling of Replacement Wells (DRILLWELL)

00 The DRILLWELL card is used to define triggering conditions related to production or injection data for wells, and the replacement well to be drilled if any of the triggering conditions are met. Note that the keyword ENDDRILLWELL must be entered to end the DRILLWELL data.

DRILLWELL NEWAPPEND

00 WELL (triggers) DRILL (QMAX) (RIGS)

00 n (values) m (qmax) (rigs)(Data card is repeated as necessary.)

00 ENDDRILLWELL

00 Definitions

NEW Alpha label indicating that this data replaces any previously specified DRILLWELL data. This is the default if neither NEW nor APPEND is entered.

APPEND Alpha label indicating that this data is added to any previously specified DRILLWELL data.

WELL Column header for a well or set of wells for which a well will be drilled if any of the trigger conditions are met. This column is required. See definition of n for the specification of this data.

DRILL Column heading for the well, or the drilling queue from which a well will be selected, to be drilled if any of the trigger conditions are met. This column is required.

QMAX Column heading for the maximum rate at which the drilled well will be set. This must be input if a well is specified in the DRILL column. The value, or the label X, will be ignored if a drilling queue is specified in the DRILL column. The units of the rate depend on the well type of the drilled well (see PROD card (Section 3.4.1), or INJ card(Section 3.4.2)).

RIGS Column heading for YES or NO, indicating whether rig availability should be checked when drilling the replacement well. If this column is not specified, YES is assumed.

5000.4.4 4-315


triggers At least 1 trigger must be entered. The following column headings are available to trigger the automatic drilling of a replacement well:

Well is an injector:

MAXQGI Maximum gas injectionMAXQWI Maximum water injectionMINQGI Minimum gas injectionMINQWI Minimum water injection

Well is a producer:

MAXQG Maximum gas productionMAXQO Maximum oil productionMAXQW Maximum water productionMAXQLIQ Maximum liquid productionMINQG Minimum gas productionMINQO Minimum oil productionMINQW Minimum water productionMINQLIQ Minimum liquid productionMAXGOR Maximum gas-oil ratioMAXGLR Maximum gas-liquid ratioMAXWCUT Maximum water cutMAXWOR Maximum water-oil ratioMAXWGR Maximum water-gas ratioMAXOGR Maximum oil-gas ratio

n Name or number of the well that will be shut in if any of the trigger conditions are met. If a group of wells is specified, each well in the group will be checked against the trigger conditions. A group may be defined by specifying one of the following (the number 1 must be entered for FIELD):

GATHER #FLOSTA # AREA # FIELD #INJREG #

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m Name or number of the well to be drilled

OR

The keyword QUEUE followed by the name or number of the drilling queue. In this case, the next available well (by specified order or potential) in the queue is drilled.

If a group of wells is specified under WELL and m is a single well, the first well to meet a trigger condition will be shut in and well m will be drilled. If m is a drill queue, wells in the group will continue to be checked until either all are shut in or the drilling queue is empty.

rigs One of either YES or NO, indicating whether rig availability should be checked when drilling the replacement well.

NOTE: 1. The alpha label X may be entered in any trigger column for which data for this well is not wanted. That trigger will not be checked.

2. Once a well is replaced, it is permanently shut in. If crossflow had been specified for the shut-in well, that is turned off also.

00 Example:

00 DRILLWELLWELL MINQO MAXQW MAXQGI DRILL QMAX

00 PROD8 50 2000 X PROD8A 5000INJ2 X X 1000000 QUEUE INJ2Q 100000GATHER 2 75 3000 X PRDGC2 5000

ENDDRILLWELL

5000.4.4 4-317


4.12.5 Elapsed Time to Drill a Well (WLDRTIME)

00 The WLDRTIME card is used to define the time necessary to complete the drilling of a well in the automatic drilling option.

00 WLDRTIME Card for WELLS

WLDRTIME WELL wldelt1 delt2 ... deltn

00 WLDRTIME Card for WELL MANAGEMENT LEVELS

WLDRTIME

GATHER

FLOSTA

AREA

FIELD

inum delt

00 Definitions: for wells

wl List of wells for which elapsed times are being specified (see Section 1.5.2).

delt Time necessary to complete the drilling of a well, days. Default is 0.

00 The number of delt values must equal the number of wells in the well list.

00 Definitions: for well management levels

Alpha label indicating the level of the well management hierarchy to which the specified elapsed time applies:

GATHER Gathering CenterFLOSTA Flow StationAREA AreaFIELD Field


delt Time necessary to complete the drilling of a well in the specified well management level, days. Default is 0.

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NOTE: 1. Elapsed times can be input at the well level or at any other level of well management. The effective elapsed time for a well will be the one specified at the lowest level of the well hierarchy: i.e., the first user-specified number found in the order: well, the appropriate gathering center, the appropriate flow station, the appropriate area, and the field.

2. If WLDRTIME is specified by well management level one and only one of the GATHER, FLOSTA, AREA, or FIELD labels must be specified. There is no default. When FIELD is specified the inum entry may be omitted or the value 1 may be input; no other value will be accepted.

00 Example:

00 WLDRTIME FIELD 1 100WLDRTIME WELL 1 -1010*75

5000.4.4 4-319


4.13 Automatic Well Workovers

00 This section describes an automatic well workover package.

00 The parameter NRIGTOT must be greater than zero on the DIM card to activate the automatic workover module.

00 Required data for this option to be functional are: WRKRIG, WRKRTO, WRKFRQ, and WRKCOEF.

00 The user should refer to the DIM card for additional dimensioned variables used for workovers. The workover report can be obtained by using the keyword WRKRPT on the OUTPUT card.

00 When using the GLIMIT or WLIMIT card, the PLUG option can not be used with the new workover module.

00 The PRFLIM option cannot be used with the automatic workover module.

00 The total number of rigs defined by all WRKRIG and DRLRIG cards may not exceed the dimension NRIGTOT.

4.13.1 Workover Rig Definition (WRKRIG)

00 The WRKRIG card is used to define the workover rigs available at any well management level and all levels below it. Rigs can be added or removed at any time.

WRKRIG

GATHER

FLOSTA

AREA

FIELD

inum

ADD

REPLACE

SUBTRACT

irigs

ALLwktim mvtim

00 Definitions:

Alpha label indicating the level of the well management hierarchy to which the specified rig is available:



AREA Area.

FIELD Field.

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ADD Alpha label indicating irigs rigs should be added to the number of rigs available.

REPLACE Alpha label indicating the rigs specified should replace any previously specified rigs for this member of well management.

SUBTRACT Alpha label indicating irigs rigs should be subtracted.

irigs Number of rigs.

ALL Alpha label indicating all rigs currently assigned are to be subtracted.

wktim Time required to complete a workover, days.

mvtim Time required to move a rig, days.

NOTE: ALL can be used only with SUBTRACT. If irigs is used to subtract rigs, they are subtracted from the bottom of the list.The data wktim and mvtim are required for ADD and REPLACE.One and only one of the GATHER, FLOSTA, AREA, or FIELD labels must be specified. There is no default. When FIELD is specified the inum entry may be omitted, or the value 1 may be input; no other value will be accepted.

4.13.2 Relative Number of Workovers (WRKRTO)

00 The WRKRTO card defines the relative number of each type of workover to perform.

WRKRTO opnrto gclrto wclrto

00 Definitions:

opnrto Number of opening workovers. Default is 0.

gclrto Number of gas closing workovers. Default is 0.

wclrto Number of water closing workovers. Default is 0.

NOTE: First opnrto opening workovers will be performed, followed by gclrto gas closing workovers, followed by wclrto water closing workovers,

5000.4.4 4-321


followed by opnrto opening workovers, etc. A value of zero implies no workovers of that type are to be performed.If this card is omitted no workovers will be performed.

4.13.3 Workover Calculation Frequency (WRKFRQ)

00 The WRKFRQ card is used to specify the frequency with which the workover calculations are performed when predictive well management (PWM) is not used. The workover calculations are automatically performed whenever PWM calculations are done.

WRKFRQ freq

MONTHS

DAYS

TSTEPS

00 Definitions:

freq Frequency with which the workover calculations will be performed. Default is 99999 timesteps.




NOTE: Within the simulator the date on a DATE card is considered to be the beginning of that day. For example, if output is desired at the end of March 1988, the date card should contain 1/4/88 and not 31/3/88. Thus the MONTHS option on the frequency card will force a timestep to start at the date 1/month/year.

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4.13.4 Elapsed Time Between Workovers (WRKDLT)

00 The WRKDLT card is used to define the elapsed time between the end of a workover and the beginning of the next.

00 WRKDLT Card for WELLS

WRKDLT WELL wldelt1 delt2. . .deltn

00 WRKDLT Card for WELL MANAGEMENT LEVELS

WRKDLT

GATHER

FLOSTA

AREA

FIELD

inum delt


wl List of wells for which elapsed times are being specified (see Section 1.5.2).

delt Elapsed time that must occur between the end of a workover and the beginning of the next workover on a well, days. Default is 0.

00 The number of delt values must equal the number of wells in the well list.


Alpha label indicating the level of the well management hierarchy to which the specified elapsed time applies:



AREA Area.

FIELD Field.


delt Elapsed time that must occur between the end of a workover and the beginning of the next workover on a

5000.4.4 4-323


well under the specified well management level, days. Default is 0.

NOTE: Elapsed times can be input at the well level or at any other level of well management. The effective elapsed time for a well will be the one specified at the lowest level of the well hierarchy: i.e., the first user-specified number found in the order: well, the appropriate gathering center, the appropriate flow station, the appropriate area, and the field.If WRKDLT is specified by well management level one and only one of the GATHER, FLOSTA, AREA, or FIELD labels must be specified. There is no default. When FIELD is specified the inum entry may be omitted or the value 1 may be input; no other value will be accepted.

4.13.5 Workover Failure Rate (WRKFAIL)

00 The WRKFAlL card defines the failure rate of workovers.

WRKFAIL ifail

00 Definition:

ifail Frequency of workover failure. Default is 0.

00 Every ifail-th workover will fail, if ifail is positive. A non-positive value implies that workovers never fail.

4.13.6 Well Limit for Automatic Shutoffs (WRKWLM)

00 The WRKWLM card defines global gas-oil ratio and water-cut limits below which a well will not be considered a candidate for automatic shutoffs for gas and water, respectively.

WRKWLM gorwlm wctwlm

00 Definitions:

gorwlm Well gas-oil ratio limit below which a well will not be considered a candidate for automatic gas shutoff, SCF/STB (SM3/STM3). Default is wells are always eligible.

wctwlm Well water-cut limit below which a well will not be considered a candidate for automatic water shutoff, fraction. Default is wells are always eligible.

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4.13.7 Workover Benefit Function Limits (WRKLIM)

00 The WRKLIM card is used to define workover benefit function limits.

00 WRKLIM Card for WELLS

WRKLIM WELL wl(OPMIN opmin1 opmin2 ... opminn)(GPMIN gpmin1 gpmin2 ... gpminn)(WPMIN wpmin1 wpmin2 ... wpminn)(MINQO minqo1 minqo2 ... minqon)(MINQG minqg1 minqg2 ... minqgn)(MINQW minqw1 minqw2 ... minqwn)(MAXWCUT mxwc1 mxwc2 ... mxwcn)(MAXGOR mxgor1 mxgor2 ... mxgorn)(MINWCUT mnwc1 mnwc2 ... mnwcn)(MINGOR mngor1 mngor2 ... mngorn)(WSMIN wsmin1 wsmin2 ... wsminn)(GSMIN gsmin1 gsmin2 ... gsminn)

00 WRKLIM Card for WELL MANAGEMENT LEVELS

WRKLIM

GATHER

FLOSTA

AREA

FIELD

inum(OPMIN opmin)(GPMIN gpmin)(WPMIN wpmin)(MINQO minqo)(MINQG minqg)(MINQW minqw)(MAXWCUT mxwc)(MAXGOR mxgor)(MINWCUT mnwc)(MINGOR mngor)(WSMIN wsmin)(GSMIN gsmin)


wl List of wells for which workover limit data is being specified (see Section 1.5.2).

opmin Minimum workover benefit value for oil perforations, STB/D (STM3/D). Default is 0.

5000.4.4 4-325


gpmin Minimum workover benefit value for gas perforations, MSCF/D (SM3/D). Default is 0.

wpmin Minimum workover benefit value for water perforations, STB/D (STM3/D). Default is 0.

minqo Minimum oil rate in an openable (oil) perforation, STB/D (STM3/D). Default is 0.

minqg Minimum gas rate in an openable (gas) perforation, MSCF/D (SM3/D). Default is 0.

minqw Minimum water rate in an openable (water) perforation, STB/D (STM3/D). Default is 0.

mxwc Maximum water cut in an openable (oil or gas) perforation, fraction. Default is 1.

mxgor Maximum gas-oil ratio in an openable (oil) perforation, SCF/STB (SM3/STM3). Default is 1.E20.

mnwc Minimum water cut in a shutable (water) perforation, fraction. Default is 0.

mngor Minimum gas-oil ratio in a shutable (gas) perforation, SCF/STB (SM3/STM3). Default is 0.

wsmin Minimum workover benefit value for water shutoffs, STB/D (STM3/D). Default is 0.

gsmin Minimum workover benefit value for gas shutoffs, MSCF/D (SM3/D). Default is 0.

00 The number of opmin, gpmin, wpmin, minqo, minqg, minqw, mxwc, mxgor, mnwc, mngor, wsmin, and gsmin values must equal the number of wells in the well list.





AREA Area.

FIELD Field.


4-326 5000.4.4


opmin Minimum workover benefit value for oil perforations, STB/D (STM3/D). Default is 0.

gpmin Minimum workover benefit value for gas perforations, MSCF/D (SM3/D). Default is 0.

wpmin Minimum workover benefit value for water perforations, STB/D (STM3/D). Default is 0.

minqo Minimum oil rate in an openable (oil) perforation, STB/D (STM3/D). Default is 0.

minqg Minimum gas rate in an openable (gas) perforation, MSCF/D (SM3/D). Default is 0.

minqw Minimum water rate in an openable (water) perforation, STB/D (STM3/D). Default is 0.

mxwc Maximum water cut in an openable (oil or gas) perforation, fraction. Default is 1.

mxgor Maximum gas-oil ratio in an openable (oil) perforation, SCF/STB (SM3/STM3). Default is 1.E20.

mnwc Minimum water cut in a shutable (water) perforation, fraction. Default is 0.

mngor Minimum gas-oil ratio in a shutable (gas) perforation, SCF/STB (SM3/STM3). Default is 0.

wsmin Minimum workover benefit value for water shutoffs, STB/D (STM3/D). Default is 0.

gsmin Minimum workover benefit value for gas shutoffs, MSCF/D (SM3/D). Default is 0.

NOTE: Workover limit values can be input at the well level or at any other level of well management. The effective values for a well will be the one specified at the lowest level of the well hierarchy; i.e., the first user-specified number found in the order: well, the appropriate gathering center, the appropriate flow station, the appropriate area, and the field.If WRKLIM is specified by well management level, one and only one of the GATHER, FLOSTA, AREA, or FIELD labels must be specified. There is no default. When FIELD is specified the inum entry may be omitted or the value 1 may be input; no other value will be accepted.

4.13.8 Group Numbers for "Group 1" (WRKGP1)

00 The WRKGP1 card is used to define the "Group 1" group number in which a well

5000.4.4 4-327


lies. This allows more flexibility in the use of the benefit functions.

00 WRKGP1 Card for WELLS

WRKGP1 WELL wligp11 igp12 . . . igp1n

00 WRKGP1 Card for WELL MANAGEMENT LEVELS

WRKGP1

GATHER

FLOSTA

AREA

FIELD

inum igp1


wl List of wells for which group numbers are being specified (see Section 1.5.2).

igp1 "Group 1" group number for the well. Default is NWRKG1+1.

00 The number of igp1 values must equal the number of wells in the well list.


Alpha label indicating the level of the well management hierarchy to which the specified "Group 1" group number applies:



AREA Area.

FIELD Field.


igp1 "Group 1" group number for each well under the specified well management level. Default is NWRKG1+1.

NOTE: "Group 1" group numbers can be input at the well level or at any other level of well management. The effective "Group 1" group number for a

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well will be the one specified at the lowest level of the well hierarchy; i.e., the first user-specified number found in the order: well, the appropriate gathering center, the appropriate flow station, the appropriate area, and the field.If WRKGP1 is specified by well management level, one and only one of the GATHER, FLOSTA, AREA, or FIELD labels must be specified. There is no default. When FIELD is specified the inum entry may be omitted or the value 1 may be input; no other value will be accepted.

4.13.9 Group Numbers for "Group 2" (WRKGP2)

00 The WRKGP2 card is used to define the "Group 2" group number in which a well lies. This allows more flexibility in the use of the benefit functions.

00 WRKGP2 Card for WELLS

WRKGP2 WELL wligp21 igp22 . . . igp2n

00 WRKGP2 Card for WELL MANAGEMENT LEVELS

WRKGP2

GATHER

FLOSTA

AREA

FIELD

inum igp2


wl List of wells for which group numbers are being specified (see Section 1.5.2).

igp2 "Group 2" group number for the well. Default is NWRKG2+1.

00 The number of igp2 values must equal the number of wells in the well list.


Alpha label indicating the level of the well management hierarchy to which the specified "Group 2" group number applies:



5000.4.4 4-329


AREA Area.

FIELD Field.


igp2 "Group 2" group number for each well under the specified well management level. Default is NWRKG2+1.

NOTE: "Group 2" group numbers can be input at the well level or at any other level of well management. The effective "Group 2" group number for a well will be the one specified at the lowest level of the well hierarchy; i.e., the first user-specified number found in the order: well, the appropriate gathering center, the appropriate flow station, the appropriate area, and the field.If WRKGP2 is specified by well management level one and only one of the GATHER, FLOSTA, AREA, or FIELD labels must be specified. There is no default. When FIELD is specified the inum entry may be omitted or the value 1 may be input; no other value will be accepted.

4.13.10 “Group 1” Default Coefficients (WRKCF1)

00 WRKCF1 card for GROUPS

WRKCF1 GROUP glcoef11 coef12 . . . coef1n

00 WRKCF1 card for WELLS

WRKCF1 WELL wlcoef11 coef12 . . . coef1n

00 Definitions: for groups

gl List of groups for which "Group 1" coefficients are being specified (see Section 1.5.2).

coef1 "Group 1" coefficients for each well in the group. Default is 1.

00 The number of coef1 values must equal the number of groups in the group list.


4-330 5000.4.4


wl List of wells for which "Group 1" coefficients are being specified (see Section 1.5.2).

coef1 "Group 1" coefficient to use for the well. Default is 1.

00 The number of coef1 values must equal the number of wells in the well list.

NOTE: The default values for "Group 1" coefficients for each well in the group can be specified by using the first form of the card. Subsequently, the defaults can be changed for specific wells by specifying coefficients by well.

4.13.11 “Group 2” Default Coefficients (WRKCF2)

00 WRKCF2 card for GROUPS

WRKCF2 GROUP glcoef21 coef22 . . . coef2n

00 WRKCF2 card for WELLS

WRKCF2 WELL wlcoef21 coef22 . . . coef2n

00 Definitions: for groups

gl List of groups for which "Group 2" coefficients are being specified (see Section 1.5.2).

coef2 "Group 2" coefficients for each well in the group. Default is 1.

00 The number of coef2 values must equal the number of groups in the group list.


wl List of wells for which "Group 2" coefficients are being specified (see Section 1.5.2).

coef2 "Group 2" coefficient to use for the well. Default is 1.

00 The number of coef2 values must equal the number of wells in the well list.

NOTE: The default values for "Group 2" coefficients for each well in the group can be specified by using the first form of the card. Subsequently, the defaults can be changed for specific wells by specifying coefficients by

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well.

4.13.12 Coefficients for Workover Benefit Functions (WRKCOEF)

00 WRKCOEF Card for WELLS

WRKCOEF WELL wlA a1 a2 . . . anB b1 b2 . . . bnC c1 c2 . . . cnD d1 d2 . . . dnE e1 e2 . . . en

00 WRKCOEF Card for WELL MANAGEMENT LEVELS

WRKCOEF

GATHER

FLOSTA

AREA

FIELD

inum a b c d e


wl List of wells for which benefit function coefficients are being specified (see Section 1.5.2).

A Alpha label indicating coefficients for oil perforations.

B Alpha label indicating coefficients for gas perforations.

C Alpha label indicating coefficients for water perforations.

D Alpha label indicating coefficients for gas shutoff.

E Alpha label indicating coefficients for water shutoff.

a Oil perforation coefficients for wells. Default is 0.

b Gas perforation coefficients for wells. Default is 0.

c Water perforation coefficients for wells. Default is 0.

d Gas shutoff coefficients for wells. Default is 0.

e Water shutoff coefficients for wells. Default is 0.

4-332 5000.4.4


00 The number of a, b, c, d and e values must equal the number of wells in the well list.


Alpha label indicating the level of the well management hierarchy to which the specified workover benefit function coefficients apply:



AREA Area.

FIELD Field.


a Oil perforation coefficient for each well under the specified well management level. Default is 0.

b Gas perforation coefficient for each well under the specified well management level. Default is 0.

c Water perforation coefficient for each well under the specified well management level. Default is 0.

d Gas shutoff coefficient for each well under the specified well management level. Default is 0.

e Water shutoff coefficient for each well under the specified well management level. Default is 0.

00 Note:

00 The benefit functions for workovers are defined as:

00 BFop =GP1i * GP2j * ( a * Op+ b * Gp+c * Wp)BFgs =GP1i * GP2j * ( d * Gs )BFws =GP1i * GP2j * ( e * Ws )

00 where:

BFop opening benefit function,

BFgs gas shutoff benefit function,

BFws water shutoff benefit function,

GP1i i-th Group 1 coefficient (WRKCF1),

5000.4.4 4-333


GP2j j-th Group 2 coefficient (WRKCF2),

Op workover benefit for oil perforations, defined as the sum of oil rates in openable perforations,

Gp workover benefit for gas perforations, defined as the sum of gas rates in openable perforations,

Wp workover benefit for water perforations, defined as the sum of water rates in openable perforations,

Gs workover benefit for gas shutoffs, defined as the sum of gas rates in shutable perforations,

Ws workover benefit for water shutoffs, defined as the sum of water rates in shutable perforations.

00 Only one of the coefficients a, b and c can be nonzero.

00 The coefficients b and d cannot both be nonzero.

00 The coefficients c and e cannot both be nonzero.

00 Benefit function coefficients can be input at the well level or at any other level of well management. The effective coefficient values for a well will be the one specified at the lowest level of the well hierarchy; i,e., the first user-specified number found in the order: well, the appropriate gathering center, the appropriate flow station, the appropriate area, and the field.

00 If WRKCOEF is specified by well management level, one and only one of the GATHER, FLOSTA, AREA, or FIELD labels must be specified. There is no default. When FIELD is specified the inum entry may be omitted or the value 1 may be input; no other value will be accepted.

4.13.13 Debug Output (WRKDBG)

00 The WRKDBG card is used to obtain debug output during the workover calculations.

WRKDBG kwrkdb

00 Definition:

kwrkdb Level of debug output:

3 Well and workover reports are printed after completion of workovers, If set to -

4-334 5000.4.4


3, the rig distribution table is also printed.

2 Workover report is printed after completion of workovers, If set to -2, the rig distribution table is also printed.

1 Rig distribution table is printed at the end of input.

0 No debug output. This is the default.

4.14 Fluid Tracking (Not available in VIP-THERM)

4.14.1 Fluid Tracking Option (TRACK)

00 The TRACK card is required to use the fluid tracking option.

00 The TRACK card is used to define data relating to the fluid tracking option.

TRACK(WTC wtc1 wtc2 ... wtcnfl)(WTV wtv1 wtv2 ... wtvnfl)(CONDENSATE retrog cgas)(TRKTOL trktlo trktlg)(NOWELL)(TRCKOF)

00 Definitions:

wtc Weighting factor for each tracked fluid used in the calculation of the mass transfer terms for condensation. Default is 1.0.

wtv Weighting factor for each tracked fluid used in the calculation of the mass transfer terms for vaporization. Default is 1.0.

retrog Number of the retrograde tracked fluid.

cgas Number of the tracked fluid which forms retrograde.

trktlo Oil phase residual tolerance. If the tolerance is violated, a warning message is written. Default is 0.00001.

trktlg Gas phase residual tolerance. If the tolerance is violated, a warning message is written. Default is 0.00001.

5000.4.4 4-335


NOWELL Alpha label specifying that production information on the well level will not be written into the track file. Default is to write the information.

TRCKOF Turns off tracking from this point on.

NOTE: The number of wtc and/or wtv values must equal the number of tracked fluids.

4.14.2 Tracked Fluid Number (YINJT)

00 The YINJT card allows the user to specify the number of the tracked fluid into which the injected gas will go.

YINJT wlyinjt1 yinjt2 ... yinjtn

00 Definitions:

wl List of gas injection wells for which yinjt values are being specified (see Section 1.5.2).

yinjt Number of the tracked fluid into which the injected gas will go. Default is 0, indicating that the injected gas will not be tracked.

NOTE: The number of yinjt values must equal the number of wells in the well list.

4.14.3 Activates Tracked Fluid Composition Output (OPRSYS)

00 The OPRSYS card activates the output of produced tracked fluid compositions, by pressure system, to Fortran unit 37. This output can only be obtained for predictive well management cases (PREDICT card) and the frequency of output is controlled by the WTRACK card. It should be entered in the TRACK data group.

OPRSYS (GATHER)

4-336 5000.4.4


00 Definition:

GATHER Alpha label that causes output to be by pressure system, on a gathering center level. The default is that output will be on a flow station level.

00 Information in the output file is organized in the form of time records. Each time record contains the following information (format):

00 ITIME,TIME (I10,E15.7)NC,NFLTRK,NGCFS,NPRSYS (4l5)start ISYS loop (ISYS=1 ,NPRSYS)ISYS (’PSYS ’ ,I5)start IGC loop (IGC=1 ,NGCFS)IGC (for LFSTRK=.TRUE.) (’FLST ’ ,I5)IGC (for LFSTRK=.FALSE.) (’GC ’ ,I5)((ZZ(I,J,IGC,ISYS) ,I=1 ,NC) ,J=1 ,NFLTRK) (8E15.7)((YY(I,J,IGC,ISYS) ,I=1 ,NC) ,J=1 ,NFLTRK) (8E15.7)end ISYS loopend IGC loop

00 where:

ITIME Time step number.

TIME Time from the start of simulation, days,

NC Number of hydrocarbon components.

NFLTRK Number of tracked fluids.

NGCFS A number equal to the number of gathering stations or flow stations depending on the value of the logical LFSTRK.

NPRSYS Number of pressure systems.

LFSTRK Logical variable, which is set to .TRUE. when the output on the flow station level is requested (default). Otherwise, LFSTRK is set to .FALSE.

ZZ(I,J,K,L) Total molar production rate (moles/day) of the component I, produced as the track fluid J, from the flow station (gathering center) K, and pressure system L.

YY(I,J,K,L) Gas molar production rate (moles/day) of the component I, produced as the track fluid J, from the flow station (gathering center) K, and pressure system L.

5000.4.4 4-337


4.15 Water Tracking (Not available in VIP-THERM)

4.15.1 Tracked Water Mixing Parameter (FTWMIX)

00 The FTWMIX card allow the user to specify how much of the insitu (connate) water in a block will be considered mobile, in calculating the fractional flow of each tracked water type. The irreducible water saturation (Swirr) can be completely bypassed, or can be partially replaced by other water types. This does not affect total water flow, but only the allocation of this water flow among the various tracked water types.

FTWMIX ftwmix

00 Definition:

ftwmix Tracked water mixing parameter; 0.0 ftwmix 1.0. A value of 0.0 implies that insitu water below the irreducible water saturation for the block is immobile. A value of 1.0 implies that all of the insitu water is mobile and that Swirr will be composed of a mix of tracked water types. Any value in between will yield a linear combination of the two. The default is 1.0.

4.15.2 Tracked Water Type Number (WINJT)

00 The WINJT card allows the user to specify the index number of the tracked water type into which the injected water will go.

WINJT wlwinjt1 winjt2 ... winjtn

00 Definitions:

wl List of water injection wells for which winjt values are being specified (see Section 1.5.2).

winjt Number of the tracked water type into which the injected water will go. Default is 0, indicating that the injected water will not be tracked.

NOTE: The number of winjt values must equal the number of wells in the well list.

4-338 5000.4.4

Chapter

5

00000Predictive Well Management1

5.1 Introduction

00 This section describes the data required to use the predictive well management (PWM) option in VIP-EXECUTIVE. The PREDICT card must appear on every run, including any history runs, of a sequence of runs in which predictive well management may be used. A WMITN card with a value greater than zero is required to invoke the PWM calculations. The variable dimensioned arrays used in PWM are described in the DIM card.

00 THP and PTARG cards are used in both basic well management and predictive well management. If used for PWM data specifications, the formats described in this section should be used.

00 When the PRINT FIELD option is selected and PWM is active, in addition to the field production and injection reports, a report of production by pressure system will be printed.

00 This section is divided into three parts: the first part describes the keywords common to both "NEW" PWM and "MGOR" PWM; the second part describes the keywords used in NEW PWM; and the third part describes the keywords used in MGOR PWM.

00 The number of pressure systems (NPRSYS on the DIM card) must be two for MGOR PWM.

00 Artificial lift is available only for pressure system one in MGOR PWM.

1. Not available in VIP-THERM

5000.4.4 5-339


5.2 Keywords Common to NEW PWM and MGOR PWM

5.2.1 Predictive Well Management (PREDICT)

00 If the PREDICT card is entered, it must occur along with other utility data.

PREDICTNEW

MGOR

00 Definitions:

PREDICT Alpha label that causes arrays that will be used in predictive well management to be defined.

NEW "NEW" predictive well management algorithm. This is the default.

MGOR "MGOR" predictive well management algorithm.

00 The PREDICT card must appear on every run, including any history runs, of a sequence of runs in which predictive well management may be used.

00 The predictive well management package will not be executed unless a nonzero value for the number of outer iterations using predictive well management is specified in the recurrent data (see WMITN card).

5.2.2 Number of Outer Iterations Each Timestep (WMITN)

00 The WMITN card must be entered to use predictive well management.

WMITN nitn (ipwmspn)

00 Definition:

nitn Number of outer iterations in each timestep that will use predictive well management. Default is 0.

ipwmspn Frequency of predictive well management calls with which surface pipeline network calculations will be done. Default is to do the surface pipeline network calculations every call to predictive well management. This value may be entered only if the surface pipeline network option has been licensed.

5-340 5000.4.4


00 The WMITN card and the PREDICT card supply the enabling data for predictive well management. Both are necessary to use this option.

00 The WMITN card defines the number of outer iterations in each timestep that will use the predictive well management set of routines to calculate well rates and bottomhole pressures.

00 It is recommended that the number of iterations be held to a small value, say 1 or 2. Larger values will probably degrade convergence considerably.

5.2.3 Pressure Systems and Lift Methods Available (PWMGC)

00 The PWMGC card is used to define which pressure systems and artificial lift methods are available in each gathering center. Producers in gathering centers with LIFT specified, for which no qlift has been input, will automatically have a negative qlift assigned.

PWMGC GATHER SYSTEM (LIFT)igc1 sysnmi (liftnm)X sysnmj (liftnm)igc2 sysnmk (liftnm). . .. . .

00 Definitions:

GATHER Alpha label indicating that the first entry on subsequent cards defines the gathering center number.

SYSTEM Alpha label indicating that the second entry on subsequent cards defines a pressure system available to the gathering center.

LIFT Alpha label indicating that the third entry on subsequent cards, if entered, defines an artificial lift method attached to the pressure system.

igc Gathering center number. For each gathering center the igc number may only be specified once.

X Alpha label indicating that the data on this card applies to the most recently specified gathering center number.

sysnm Pressure system name.

liftnm Artificial lift method name.

5000.4.4 5-341


5.2.4 Tubinghead Pressure (THP)

THP wlsysnm1 thp11 thp12. . .thp1nsysnm2 thp21 thp22. . .thp2n

. . .

. . .

. . .

00 Definitions:

wl List of wells for which thp values are being entered (see Section 1.5.2).

sysnm Name of the pressure system to which the thp values on this card apply.

thp Tubinghead pressure limit when the well points to the appropriate pressure system, psia (kPa).

NOTE: For predictive well management a tubinghead pressure value must be specified for each well for each pressure system to which the well may be produced.The number of thp values on any of the cards must equal the number of wells in the well list.To invoke THP constraints for a well, the user must also define a productivity index, BHPTAB data, and ITUBE / SYSTB data.

5.2.5 Production Target Data (PTARG)

00 A PTARG card is used to define a maximum production rate for a gathering center, a flow station, an area, or the field, or for the subunits sysnm within each entity.

PTARG

GATHER

FLOSTAAREAFIELD

inumTOTAL

sysnm

O

GW

VEL

qtarg (coil cwat cgas (cwct))LFTGAS

NOLFTGAS

5-342 5000.4.4


00 Definitions:

Alpha label indicating the level of well management hierarchy to which the specified maximum production rate applies:



AREA Area.

FIELD Field.


Alpha label indicating to which subunit (or total) the maximum rate applies:

TOTAL Alpha label indicating the maximum rate applies to the specified member as a whole, not to a particular pressure system. This is the default.

sysnm Name of the pressure system to which the maximum rate applies.





VEL “Velocity,” user-defined units (see NOTE below).

qtarg Maximum production rate or “velocity.”

coil Coefficient of the oil rate term; “velocity” option only.

cwat Coefficient of the water rate term; “velocity” option only.

cgas Coefficient of the gas rate term; “velocity” option only.

cwct Minimum water cut for “velocity” option to be invoked. Optional.

LFTGAS Alpha label indicating that the gas production target qtarg also includes the amount of gaslift gas used in the specified level of well management. This option applies only when the label G is specified.

5000.4.4 5-343


NOLFTGAS Alpha label indicating that the gas production target qtarg does not include gaslift gas. This is the default. This option applies only when the label G is specified.

NOTE: In predictive well management mode, one and only one of TOTAL or sysnm may be specified. If neither is input TOTAL is assumed. Separate maxima can be established for each pressure system by inputting multiple PTARG cards.One and only one of the GATHER, FLOSTA, AREA, or FIELD labels must be specified. There is no default. When FIELD is specified the inum entry may be omitted, or the value 1 may be input; no other value will be accepted.One and only one of the O, W, G, or VEL labels must be specified. There is no default. The label VEL applies only when the label GATHER is specified. Separate maxima can be established for oil, water and gas by reading multiple PTARG cards.The oil, water and gas maxima may be exceeded by the tolerance factors specified on the TRGTOL card before violations occur.The labels LFTGAS and NOLFTGAS apply only when the label G is specified. The values coil, cwat, cgas, and, optionally, cwct, must be entered if and only if the label VEL is specified. When the “velocity” option is invoked, the following “velocity” is computed: coil x (oil rate) + cwat x (water rate) + cgas x (gas rate). This quantity is then checked against the qtarg value in the same manner as the production maxima. If cwct is entered, the computed watercut must be larger than this in order for the “velocity” to be checked.

00 Examples:

00 PTARG FIELD 1 TOTAL G 6861PTARG GATHER 2 SYS1 W 50000PTARG AREA 1 LPSYS G 100000 LFTGAS

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5.2.6 Frequency of PWM Calculations (PWMFRQ)

PWMFRQ freq

MONTHS

DAYS

TSTEPS

00 Definitions:

freq Frequency with which the PWM calculations will be performed. Default is 99999 timesteps.




00 The PWMFRQ card is used to specify the additional frequency with which the PWM algorithm is performed. The PWM algorithm is automatically performed at every DATE/TIME card.

00 Within the simulator the date on a DATE card is considered to be the beginning of that day. For example, if output is desired at the end of March 1988, the date card should contain 1/4/88 and not 31/3/88. Thus the MONTHS option on the frequency card will force a timestep to start at the date 1/month/year.

5.2.7 Bottomhole Pressure Tables (SYSTB)

00 The SYSTB card specifies the bottomhole pressure table to be used when a well points to a pressure system with or without lift.

SYSTB wlsysnm1 (liftnm1) itb11 itb12. . .itb1nsysnm2 (liftnm2) itb21 itb22. . .itb2n

00 Definitions:

wl List of wells for which table pointers are being assigned (see Section 1.5.2).

5000.4.4 5-345


sysnm Name of the pressure system to which the table pointers on this card apply.

liftnm Name of the artificial lift method to which the table pointers on this card apply.

itb Bottomhole pressure table pointer.

NOTE: The number of table pointers on each card must equal the number of wells in the well list.If a pointer for a well for a lift method is not input, the table pointer will default to the value for the appropriate pressure system.If a pointer for a well for a pressure system is not input, the table pointer will default to the value specified on the ITUBE card for the well.

5.2.8 Define Pressure Systems for Wells During History (HISTSYS)

00 The HISTSYS card is used to define the pressure system for each well during the history period. This data is used to print production reports by pressure system during the history period.

00 HISTSYS Card for WELLS

HISTSYS WELL wlsysnm1 sysnm2 . . . sysnmn

00 HISTSYS Card for WELL MANAGEMENT LEVELS

HISTSYS

GATHER

FLOSTA

AREA

FIELD

inum sysnm


wl List of wells for which pressure systems are being specified (see Section 1.5.2).

sysnm Pressure system name for the well.

00 The number of sysnm values must equal the number of wells in the well list.

5-346 5000.4.4



Alpha label indicating the level of the well management hierachy to which the specified pressure system name applies:



AREA Area.

FIELD Field.


sysnm Pressure system name for each well under the specified well management level.

NOTE: Pressure system names can be input at the well level or at any other level of well management. The effective pressure system for a well will be the one specified at the lowest level of the well hierarchy; i.e., the first user-specified number found in the order: well, the appropriate gathering center, the appropriate flow station, the appropriate area, and the field.If HISTSYS is specified by well management level, one and only one of the GATHER, FLOSTA, AREA, or FIELD labels must be specified. There is no default. When FIELD is specified the inum entry may be omitted or the value 1 may be input; no other value will be accepted.

5.2.9 Defining Pressure Systems (PRSYS)

00 The PRSYS card defines the names of the PWM pressure systems.

PRSYS sysnm1 sysnm2. . . sysnmNPRSYS

00 Definition:

sysnm sysnm1 is the name of the pressure system with the lowest tubinghead pressure, sysnm2 is the name of the pressure system with the next higher tubinghead pressure, etc.

NOTE: The pressure system names can be up to eight (8) characters long. If this card is omitted the pressure systems are denoted as SYS1, SYS2, ...,SYSn. The user can selectively use default names by specifying X for a name in the above card.

5000.4.4 5-347


00 Examples:

00 If NPRSYS = 3, the following are valid PRSYS cards:PRSYS SYSTM1 SYSTM2 SYSTM3PRSYS LOWPRS X HIGHPR (here X = SYS2)PRSYS SYS1 SYS2 SYS3

5.2.10 Artificial Lift Method Names (ARTLFT)

00 The ARTLFT card defines the names of the artificial lift methods.

ARTLFT alftnm1 alftnm2 ... alftnmNPWMAL

00 Definition:

alftnm Name of artificial lift method #n

00 The artificial lift method names can be up to eight (8) characters long. If this card is omitted, the default name for lift method #1 is GASLFT.

5.2.11 Tolerance for Production Rates (PWMTLP, NONPWM, TRGPWM)

00 The PWMTLP card is used to define the tolerance within which the rates in non-PWM timesteps must fall. It also defines the action to perform if a violation occurs.

PWMTLP

GATHER

FLOSTA

AREA

FIELD

inum

ALL

TOTAL

sysnm O

G

W

NONPWM tolr1

STOP

WARN

WMAN

TRGPWM tolr2

STOP

WARN

WMAN

5-348 5000.4.4


00 Definitions:




AREA Area.

FIELD Field.


ALL Alpha label indicating the tolerance applies to all members in the specified well management level.

TOTAL Alpha label indicating the data applies to the specified member as a whole, not to a particular pressure system. This is the default.

sysnm Name of the pressure system to which the data applies.

Alpha label indicating the tolerance applies to the rates:

O Oil production

G Gas production.

W Water production.

NONPWM Alpha label indicating the data on this card applies to the comparison of the rates from non-PWM timesteps to the PWM timestep.

tolr1 Tolerance within which the rate for a non-PWM timestep must fall. That is, a violation occurs if

(RATE(PWM) - RATE(NON-PWM))/RATE(PWM) > tolr1

Default is to not do the comparison if the NONPWM card is not input.

TRGPWM Alpha label indicating the data on this card applies to the comparison of the rates from non-PWM timesteps to the targets.

tolr2 Tolerance within which the rate for a non-PWM timestep must fall. That is, a violation occurs if

5000.4.4 5-349


(RATE(NON-PWM) - TARGET) / TARGET > tolr2

Default is to not do the comparison if the TRGPWM card is not input.

Alpha label indicating the action to take if a violation occurs:

STOP Write a restart record and stop the run.

WARN Write a warning message and continue the run.

WMAN Repeat this timestep performing the PWM algorithm.

NOTE: One and only one of the GATHER, FLOSTA, AREA, or FIELD labels must be specified. There is no default, When FIELD is specified the inum entry may be omitted or the value 1 may be input; no other value will be accepted.One and only one of the O, W, or G labels must be specified. There is no default.One and only one of TOTAL or sysnm may be specified. If neither is input TOTAL is assumed. Separate tolerances can be established for each pressure system by inputting multiple PWMTLP cards.Either one or both of the NONPWM and TRGPWM cards may be input.

5.2.12 Oil Incremental Benefit with Gaslift (PWMOBN)

00 The PWMOBN card is used to specify the oil incremental benefit with gaslift.

PWMOBN bnf

00 Definition:

bnf Fraction of the non-lifted oil rate above which gaslift must improve in order to be eligible. Default is 0.05.

5.2.13 Maximum PWM Timestep Size (DTPWM)

00 The DTPWM card is used to specify the maximum allowable timestep size for a predictive well management timestep.

DTPWM dtpwm

00 Definition:

5-350 5000.4.4


dtpwm Maximum allowable timestep size that can be used for a predictive well management timestep, days. Default is no size restriction.

5.2.14 Write PWM Report to File (PWMFILE)

00 The PWMFILE card is used to request a report of pressure system production rates written in spreadsheet format to FORTRAN Unit 63.

PWMFILETIMETNEXTOFF

freq

00 Definitions:

TIME Alpha label that causes the file to be written each time a TIME or DATE card is encountered. Default is not to write on the basis of TIME or DATE cards.

TNEXT Alpha label that causes the file to be written only the next time a TIME or DATE card is encountered. Default is not to write on the basis of the next TIME or DATE card.

OFF Alpha label that causes the file not to be output. It is equivalent to specifying a frequency of 99999.

freq A number that causes the file to be written after every freq timesteps (each timestep cut counts as one timestep). Default is 99999.

NOTE: At least one of the values, TIME, TNEXT, OFF, or freq must appear on the PWMFILE card. Either TIME or TNEXT may appear with freq. The records are written to FORTRAN Unit 63, which may not be saved unless the appropriate commands are added to the job control stream.

5.2.15 Debug Output (PWMDBG)

00 The PWMDBG card is used to obtain debug output during the PWM calculations.

PWMDBG idbg (NEXTONLY)(ALL)

00 Definitions:

5000.4.4 5-351


idbg Level of debug output for "NEW" PWM":

3 Well and well management output for each pass.

2 Well management output for each pass.

1 Well management output for each step.


idbg Level of debug output for "MGOR" PWM:

4 Information at the operating points for the wells specified on the WPWMDB card, plus the reports for lesser values of idbg.

3 Well management report each time rates are decreased to honor targets, plus the reports for lesser values of idbg.

2 Well management report at the end of each iteration of incremental gas-oil ratio value, plus the report at the completion of the algorithm.

1 Well management report at the completion of the algorithm.


NEXTONLY Alpha label indicating the debug output will be printed for the next PWM calculations only. This is the default.

ALL Alpha label indicating the debug output will be printed for all subsequent PWM calculations.

5-352 5000.4.4


5.3 Keywords for NEW PWM

5.3.1 Minimum Oil Rate for Producers (QOMIN)

00 The QOMIN card is used to define the minimum oil rate a well must have in order to flow into any pressure system.

00 Each producing well must have a QOMIN value or QGMIN value, or both, specified.

00 QOMIN Card for WELLS

QOMIN WELL wlqomin1 qomin2 . . . qominn

00 QOMIN card for WELL MANAGEMENT LEVELS

QOMIN

GATHER

FLOSTA

AREA

FIELD

inum qomin


wl List of wells for which minimum oil rates are being specified (see Section 1.5.2).

qomin Minimum oil rate for the well during PWM categorization, STB/D (STM3/D).

00 The number of qomin values must equal the number of wells in the well list.


Alpha label indicating the level of the well management hierarchy to which the specified minimum oil rate applies:



AREA Area.

FIELD Field.

5000.4.4 5-353



qomin Minimum oil rate for each well under the specified well management level during PWM categorization, STB/D (STM3/D).

NOTE: Minimum oil rate values can be input at the well level or at any other level of well management. The effective minimum value for a well will be the one specified at the lowest level of the well hierarchy; i.e., the first user-specified number found in the order: well, the appropriate gathering center, the appropriate flow station, the appropriate area, and the field.If QOMIN is specified by well management level, one and only one of the GATHER, FLOSTA, AREA, or FIELD labels must be specified. There is no default. When FIELD is specified the inum entry may be omitted or the value 1 may be input; no other value will be accepted.

5.3.2 Minimum Gas Rate for Producers (QGMIN)

00 The QGMIN card is used to define the minimum gas rate a well must have in order to flow into any pressure system.

00 Each producing well must have a QOMIN value or QGMIN value, or both, specified.

00 QGMIN Card for WELLS

QGMIN WELL wlqgmin1 qgmin2 . . . qgminn

00 QGMIN Card for WELL MANAGEMENT LEVELS

QGMIN

GATHER

FLOSTA

AREA

FIELD

inum qgmin


wl List of wells for which minimum gas rates are being specified (see Section 1.5.2).

5-354 5000.4.4


qgmin Minimum gas rate for the well during PWM categorization, MSCF/D (SM3/D).

00 The number of qgmin values must equal the number of wells in the well list.


Alpha label indicating the level of the well management hierarchy to which the specified minimum gas rate applies:



AREA Area.

FIELD Field.


qgmin Minimum gas rate for each well under the specified well management level during PWM categorization, MSCF/D (SM3/D).

NOTE: Minimum gas rate values can be input at the well level or at any other level of well management. The effective minimum value for a well will be the one specified at the lowest level of the well hierarchy; i.e., the first user-specified number found in the order: well, the appropriate gathering center, the appropriate flow station, the appropriate area, and the field.One and only one of the GATHER, FLOSTA, AREA, or FIELD labels must be specified. There is no default. When FIELD is specified the inum entry may be omitted or the value 1 may be input; no other value will be accepted.

5000.4.4 5-355


5.3.3 PWM Calculation Steps (PWMSTEP)

00 The PWMSTEP card is used to specify all the data needed to perform steps 2 and 3 of the new predictive well management.

PWMSTEP 2PASS ipass (REMOVE)BENEFIT bennam (a b c d e f g h i j)PAFACT pa1 pa2 . . . paNPWMPAPMFACT pm1 pm2 . . . pmNPWMPM

WMGL

GATHER

FLOSTA

AREA

FIELD

PRSYS sysnmGORM gormGLRM glrmWCUT wcutEXCLUDE W

ACTION

CUTOFF

AVG

SCALE

CATEGORY

NOLIFTREQ

LIFTREQ

LIFTONLY

MUSTFLOW

(card 1)

MUSTLIFT (card 2)ALL .sysnm . . . .

ENDCATEGORYPASS ipass (REMOVE).ENDSTEP

5-356 5000.4.4


PWMSTEP 3 (STOP)(WARN)

PASS ipass (REMOVE)BENEFIT bennam (a b c d e f g h i j)PAFACT pa1 pa2 . . . paNPWMPAPMFACT pm1 pm2 . . . pmNPWMPM

WMGL

GATHER

FLOSTA

AREA

FIELD

PRSYS sysnm

TOTAL

PHASEO

W

G

SHUT

SCALE

AVG

PASS ipass (REMOVE).ENDSTEP

00 Definitions: for PWMSTEP 2 card

PASS Alpha label indicating data for a pass is to be input.

ipass Pass number. The value of ipass can not be greater than NPWMPS.

REMOVE Alpha label indicating the designated pass ipass should be removed from this step.

bennam Benefit function name. See notes below for benefit function definitions.

a,...,j Benefit function coefficients. See notes below.

PAFACT Alpha label indicating the factors to be used for each producing area are on this card. If the card is not input, the factors default to 1.

pa Producing area factor. Default is 1.

PMFACT Alpha label indicating the factors to be used for each producing mechanism are on this card. If the card is not input, the factors default to 1.

5000.4.4 5-357


pm Producing mechanism factor. Default is 1.

WMGL Alpha label indicating the level of the well management hierarchy to which the data for this pass applies is on this card.

Alpha label indicating the level of the well management hierarchy:



AREA Area.

FIELD Field.

PRSYS Alpha label indicating the system to be filled during this pass.

sysnm Name of the pressure system to be filled.

GORM Alpha label indicating the maximum producing GOR for wells in this pass is input on this card. This card replaces any previously specified GLRM data for this pass.

gorm Maximum producing GOR for wells in this pass, SCF/STB (SM3/ STM3).

GLRM Alpha label indicating the maximum producing GLR for wells in this pass is input on this card. This card replaces any previously specified GORM data for this pass.

glrm Maximum producing GLR for wells in this pass, SCF/STB (SM3/ STM3).

WCUT Alpha label indicating the maximum producing water-cut for wells in this pass is input on this card.

wcut Maximum producing water-cut for wells in this pass, fraction.

EXCLUDE W Alpha labels indicating that water rate constraints are not to be checked during this pass.

ACTION Alpha label indicating the procedure for meeting the target.

CUTOFF Assign wells in benefit function order until target is met. This is the default.

5-358 5000.4.4


00 Definitions: for PWMSTEP 3 card

AVG Reset the rates of the highest rate wells to an average rate to meet the target. All eligible wells are considered.

SCALE Scale all eligible wells to meet the target.

CATEGORYENDCATEGORY

Alpha labels indicating the well hydraulic categories that are eligible to be considered on this pass are input between these two cards.

NOLIFTREQ Alpha label indicating, for the pressure system categories specified on the following card(s), wells are eligible under nolift conditions only (i.e., do not consider lift rates in this pass). This is the default.

LIFTREQ Alpha label indicating, for the pressure system categories specified on the following card(s), wells are eligible under both lift and nolift conditions (i.e., if applicable the wells may appear twice in the benefit function list: for lift and non-lift rates).

LIFTONLY Alpha label indicating, for the pressure system categories specified on the following card(s), wells are eligible under lift conditions only (i.e., only consider gas lift rates for wells).

MUSTFLOW Alpha label indicating that the wells categorized as MUSTFLOW on the PWMCAT card are the eligible wells for this pass. The ALL option must be used.

The following three options are used for determining the eligible categories for the current pass:

MUSTLIFT Alpha label indicating wells that can only flow when lifted are eligible on this pass.

ALL Alpha label indicating all well hydraulic categories, including MUSTLIFT, are eligible on this pass (i.e., every unassigned well in the list is considered).

sysnm Name of the pressure system category to be included on this pass (i.e. , select wells which can flow to the pressure system sysnm).

ENDSTEP Alpha label indicating the end of the PWMSTEP data. Required.

Alpha label indicating the action to take if any targets remain in violation following step 3:

5000.4.4 5-359


STOP Write a restart record and stop the run.

WARN Write a warning message and continue the run.

PASS Alpha label indicating data for a pass is to be input.

ipass Pass number. The value of ipass cannot be greater than NPWMPS.

REMOVE Alpha label indicating the designated pass ipass should be removed from this step.

bennam Benefit function name. See notes below for benefit function definitions.

a,...,j Benefit function coefficients. See notes below.

PAFACT Alpha label indicating the factors to be used for each producing area are on this card. If the card is not input, the factors default to 1.

pa Producing area factor. Default is 1.

PMFACT Alpha label indicating the factors to be used for each producing mechanism are on this card. If the card is not input, the factors default to 1.

pm Producing mechanism factor. Default is 1.

WMGL Alpha label indicating the level of the well management hierarchy to which the data for this pass applies is on this card.

Alpha label indicating the level of the well management hierarchy:



AREA Area.

FIELD Field.

PRSYS Alpha label indicating the system to be filled during this pass.

sysnm Name of the pressure system to be filled.

TOTAL Alpha label indicating the entire well management level member is to be checked.

PHASE Alpha label indicating which phase target is to be checked and the action to be taken during this pass are input on this card.

Alpha label indicating the phase target to be checked:

5-360 5000.4.4


NOTE: Multiple sets of pass data can be input for each PWMSTEP card.The following data is required for each specified pass: BENEFIT, WMGL, PRSYS, PHASE and CATEGORY.Data for pass 1 must be specified.The action CUTOFF must be used if LIFTREQ or LIFTONLY are specified on the CATEGORY card (in step 2).The category ALL must be used if MUSTFLOW is specified on the CATEGORY card (in step 2).The following is the list of available benefit functions:

BF1: PMi *PAj *(a*Qo +b*GOR+c*WCUT+d*GLGOR)

BF2: PMi * PAj * ( a + b*Qg + c*Qo + d*Qw + e*Qglg) /

( f + g*Qg + h*Qo + i*Qw + j*Qglg)

BF3: PMi* PAj* (a+Qo)**b* ( c+GOR )** d*

( e +WCUT )**f * ( g +GLGOR )**hFor benefit function BF3, the exponents b, d, f and h should be integer values. If not, they are internally set to the nearest integer.

O Oil target.

W Water target.

G Gas target.

Alpha label indicating the action to take if a violation occurs:

SHUT Shut-in wells in the benefit function order.

SCALE Scale all eligible wells to meet the target.

AVG Reset the rates of the highest rate wells to an average rate.

ENDSTEP Alpha label indicating the end of the PWMSTEP data. Required.

5000.4.4 5-361


5.3.4 Producing Area Number (PWMWPA)

00 The PWMWPA card is used to define the producing area in which a well lies. This allows more flexibility in the use of the benefit functions.

00 PWMWPA Card for WELLS

PWMWPA WELL wlipa1 ipa2 . .. ipan

00 PWMWPA Card for WELL MANAGEMENT LEVELS

PWMWPA

GATHER

FLOSTA

AREA

FIELD

inum ipa


wl List of wells for which producing area numbers are being specified (see Section 1.5.2).

ipa Producing area number for the well. Default is NPWMPA+1.

00 The number of ipa values must equal the number of wells in the well list.


Alpha label indicating the level of the well management hierarchy to which the specified producing area number applies:



AREA Area.

FIELD Field.


ipa Producing area number for each well under the specified well management level. Default is NPWMPA+1.

5-362 5000.4.4


NOTE: Producing area numbers can be input at the well level, or at any other level of well management. The effective producing area number for a well will be the one specified at the lowest level of the well hierarchy; i.e., the first user-specified number found in the order: well, the appropriate gathering center, the appropriate flow station, the appropriate area, and the field.If PWMWPA is specified by well management level, one and only one of the GATHER, FLOSTA, AREA, or FIELD labels must be specified. There is no default. When FIELD is specified the inum entry may be omitted or the value 1 may be input; no other value will be accepted.

5.3.5 Producing Mechanism (PWMWPM)

00 The PWMWPM card is used to define the producing mechanism for a well. This allows more flexibility in the use of the benefit functions.

00 PWMWPM Card for WELLS

PWMWPM WELL wlipm1 ipm2 . . . ipmn

00 PWMWPM Card for WELL MANAGEMENT LEVELS

PWMWPM

GATHER

FLOSTA

AREA

FIELD

inum ipm


wl List of wells for which producing mechanism numbers are being specified (see Section 1.5.2).

ipm Producing mechanism number for the well. Default is NPWMPM+1.

00 The number of ipm values must equal the number of wells in the well list.


Alpha label indicating the level of the well management hierarchy to which the specified producing mechanism number applies:


5000.4.4 5-363



AREA Area.

FIELD Field.


ipm Producing mechanism number for each well under the specified well management level. Default is NPWMPM+1.

NOTE: Producing mechanism numbers can be input at the well level or at any other level of well management. The effective producing mechanism number for a well will be the one specified at the lowest level of the well hierarchy; i.e., the first user-specified number found in the order: well, the appropriate gathering center, the appropriate flow station, the appropriate area, and the field.If PWMWPM is specified by well management level, one and only one of the GATHER, FLOSTA, AREA, or FIELD labels must be specified. There is no default. When FIELD is specified the inum entry may be omitted or the value 1 may be input; no other value will be accepted.

5.3.6 Define Well Category (PWMCAT)

00 The PWMCAT card is used to explicitly define the PWM category for a well.

PWMCAT MUSTFLOW sysnm

DECLASS (liftnm) wl

00 Definitions:

sysnm Name of the pressure system to which the wells are explicitly categorized.

MUSTFLOW Alpha label indicating that the wells listed on this card are eligible when MUSTFLOW is specified on the CATEGORY card in the PWMSTEP 2 data. Also, these wells are not eligible for rate reduction during the Step 3 process.

DECLASS Alpha label indicating that the wells are to be declassified; i.e., remove any previous explicit categorization.

5-364 5000.4.4


liftnm Name of the artificial lift method to which the wells are additionally categorized.

wl List of wells which are being explicitly categorized (see Section 1.5.2).

5.3.7 MUSTFLOW Well Specification (MUSTFLOW)

00 The MUSTFLOW card is used to affect the eligibility of wells when MUSTFLOW is specified on the CATEGORY card in the PWMSTEP 2 data. Also, MUSTFLOW wells are not eligible for rate reduction during the Step 3 process.

MUSTFLOW ONOFF wl

00 Definitions:

ON Alpha label indicating that the wells listed on this card are to be considered MUSTFLOW wells. This is the default if neither ON nor OFF is specified.

OFF Alpha label indicating that the wells listed on this card are not to be MUSTFLOW wells.

wl List of wells which are either being assigned or unassigned as MUSTFLOW wells (see Section 1.5.2).

5.3.8 Minimum Oil Rate for Wells on Gaslift (QOMINL)

00 The QOMINL card is used to define the minimum oil rate a well on gaslift must have in order to flow into any pressure system.

00

00 QOMINL Card for WELLS

QOMINL WELL wlqominl1 qominl2... qominln

00

00

5000.4.4 5-365


00 QOMINL Card for WELL MANAGEMENT LEVELS

QOMINL

GATHER

FLOSTA

AREA

FIELD

inum qominl


wl List of wells for which minimum oil rates are being specified (see Section 1.5.2).

qominl Minimum oil rate for the well on gaslift during PWM categorization, STB/D (STM3/D).

00 The number of qominl values must equal the number of wells in the well list.


Alpha label indicating the level of the well management hierachy to which the specified minimum oil rate applies:



AREA Area.

FIELD Field.


qominl Minimum oil rate for each well under the specified well management level on gaslift during PWM categorization, STB/D (STM3/D).

NOTE: Minimum oil rate values can be input at the well level or at any other level of well management. The effective minimum value for a well will be the one specified at the lowest level of the well hierarchy; i.e., the first user-specified number found in the order: well, the appropriate gathering center, the appropriate flow station, the appropriate area, and the field.If the qominl value is not specified for a well, the qomin value will be used.One and only one of the GATHER, FLOSTA, AREA, or FIELD labels must be specified. There is no default. When FIELD is specified the inum

5-366 5000.4.4


entry may be omitted or the value 1 may be input; no other value will be accepted.

5.3.9 Execute Normal Targeting Procedure (PWMTRG)

00 The PWMTRG card is used to force the execution of the normal targeting procedure for checking well management level production constraints, even during PWM iterations.

PWMTRG ONOFF

00 Definitions:

00 ON Alpha label indicating that the normal targeting procedure should be used to check production constraints.

00 OFF Alpha label indicating that the normal targeting procedure should not be used. This is the default if the card is not entered.

5.3.10 Frequency of Pressure System Switching (PRSDLT)

00 The PRSDLT card is used to define the length of time a well must be assigned to a pressure system before it can be switched to another.

PRSDLT frqsys1 frqsys2 ...frqsysNPRSYS

00 Definition:

00 frqsys Length of time a well must be assigned to this pressure system before it can be switched to another pressure system, days. The alpha label X may be entered instead of a value to indicate the value should not be changed.

5.3.11 Well Rate Control (PWMWCN)

00 The PWMWCN card is used to specify how wells are to be handled during non-PWM iterations and timesteps. Wells are either considered bottomhole pressure controlled wells, where the bottomhole pressure limit is the value from the last

5000.4.4 5-367


PWM iteration, or rate controlled.

PWMWCN

BHPOIL

WATERGAS

LIQUID

00 Definitions:

BHP Alpha label indicating that the wells should be treated as bottomhole pressure controlled. This is the default.

OIL Alpha label indicating that the wells should be treated as oil rate controlled.

WATER Alpha label indicating that the wells should be treated as water rate controlled.

GAS Alpha label indicating that the wells should be treated as gas rate controlled.

LIQUID Alpha label indicating that the wells should be treated as liquid rate controlled.

5-368 5000.4.4


5.4 Keywords for MGOR PWM

5.4.1 Separator Battery Numbers (SYSSEP)

00 The SYSSEP card is used to specify the separator battery number to be used when a well points to a pressure system.

SYSSEP wlsysnm1 ibt11 ibt12 ... ibt1nsysnm2 ibt21 ibt22 ... ibt2n

00 Definitions:

wl List of wells for which separator battery numbers are being assigned (see Section 1.5.2).

sysnm Name of the pressure system to which the separator battery numbers on this card apply.

ibt Separator battery number.

NOTE: The number of separator battery numbers on each card must equal the number of wells in the well list.If a battery number for a well for a pressure system is not input, the separator battery number will default to the value specified on the WELL card for the well.

5.4.2 MGOR Option Data (PRMGOR)

00 The PRMGOR card is used to specify the data needed to execute the marginal gas-oil ratio (MGOR) option of the predictive well management algorithm.

PRMGOR (FGRBGN)(FGRINC)(WCUTLM)(FIXGL)(EFF)

(fgrbgn)(fgrinc)(wcutlm)ON

OFF ON

OFF

00 Definitions:

fgrbgn Initial value of field total incremental gas-oil ratio (TIGOR) at which to start the well assignment, SCF/STB (SM3/STM3). Default is 1000 SCF/STB.

5000.4.4 5-369


fgrinc TIGOR increment to use during the algorithm, SCF/STB (SM3/STM3). Default is 500 SCF/STB.

wcutlm Water-cut value above which a well will not be allowed to produce, fraction. Default is 1.

FIXGL Indicates the method of placing wells on gaslift:

ON Fixed gaslift gas rate. Wells are either on gaslift at the rate corresponding to the user-specified efficiency or not at all.

OFF Variable gaslift gas rate. The allocated gaslift gas rate may range from zero to the rate corresponding to the user-specified efficiency. This is the default.

EFF Indicates the method of determining the lift efficiency to use in the gaslift gas calculations under the performance curve option:

ON User-specified table of water-cut versus efficiency (EFFTAB card).

OFF User-specified value (PFMCRV card). This is the default.

5.4.3 Water-Cut Versus Efficiency Table (EFFTAB)

00 EFFTAB data are used to relate lift efficiency to the water-cut of the well.

EFFTABWCUT EFFwcut1 eff1wcut2 eff2.wcutn effn

00 Definitions:

WCUT Alpha label indicating that this column contains water-cut values.

EFF Alpha label indicating that this column contains lift efficiency values.

wcut Water-cut values, fraction.

eff Lift efficiency values for use in the performance curve option, STB/MMSCF (STM3/KSM3).

5-370 5000.4.4


NOTE: An EFFTAB card must be input if the EFF ON option is specified on the PRMGOR card.The number of water-cut (or efficiency) values must be no greater than 100.

5.4.4 Specify Wells Included in Well Debug Report (WPWMDB)

00 The WPWMDB card specifies the wells for which debug output is desired when the well debug option is specified on the PWMDBG card.

WPWMDB wl

00 Definitions:

wl List of wells for which debug output is requested (see Section 1.5.2).

5000.4.4 5-371


5-372 5000.4.4

Chapter

6

00000Output Control

6.1 Introduction

00 VIP-EXECUTIVE can generate a variety of output:

1. Timestep Summaries

2. Iteration Summaries

3. Array Reports

4. Well, Well Layer, Well Status Change, and Perf Status Change Summaries

5. Separator Reports

6. Production/Injection Reports at any well management level

7. Potential production/injection reports.

8. Simulation Statistics

9. Region Summaries

10. Well RFT Reports

11. Restart Records

12. VDB File for Post-Processing Well and Array Data

13. Plot Files for Post-Processing Well Data

14. Map Files for Post-Processing Array Data

15. Relative Permeability Files for Pseudo Function Generation

16. Echo printing of time-dependent input data

00 The user can control the content and frequency of output of all items except the timestep summaries.

5000.4.4 6-373


6.2 Print/Map Arrays and Parameters (OUTPUT, MAPOUT)

00 The OUTPUT card and MAPOUT card are used to specify which arrays are to be printed and written to the map file, respectively. The OUTPUT card is also used to enter parameters which cause specific actions to be taken.

00 The MAPOUT card may be entered only if a MAP card was specified in the VIP-CORE data set.

OUTPUT array1 ... arraym param1 . . . paramnMAPOUT array1 ... arrayk MAPOUT NONE

00 Definitions:

OUTPUT Alpha label that causes the specified arrays to be included in the array report, or the specified action to occur.

MAPOUT Alpha label that causes the specified arrays to be written to the map file.

NONE Alpha label that causes no arrays to be written to the map file.

array Alpha label of those arrays being defined on either an OUTPUT card or a MAPOUT card:

P Pressure.

PSAT Saturation pressure.

PDAT Datum pressure.

PMIN Minimum pressure. Available only when the irreversible rock compaction option is in use.

PCGO Gas-oil capillary pressure.

PCWO Water-oil capillary pressure.

PCGW Gas-water capillary pressure. Available only when the GASWATER option is in use.

SO Oil saturation.

SW Water saturation.

6-374 5000.4.4


SG Gas saturation.

SOM Normalized mobile oil saturation.

SWM Normalized mobile water saturation.

RS Solution gas-oil ratio.

RV Solution oil-gas ratio.

BOF Oil formation volume factor.

BG Gas formation volume factor.

GOR Total gas-oil ratio.

WCUT Water cut.

RSW Solution gas-water ratio. Available only when the CO2 option is in use.

VISO Oil phase viscosity.

VISG Gas phase viscosity.

VISW Water viscosity.

DENO Oil phase density.

DENG Gas phase density.

PV Pore volume including compaction effects.

TX X direction transmissibility including compaction effects.

TY Y direction transmissibility including compaction effects.

TZ Z direction transmissibility including compaction effects.

TR R direction transmissibility including compaction effects.

TTHETA Angular-direction transmissibility including compaction effects.

ITRAN Transmissibility region.

KRO Relative permeability of the oil phase. Keywords KROX+, KROX-, KROY+,

5000.4.4 6-375


KROY-, KROZ+, KROZ- can be used for directional relative permeabilities in X+, X-, Y+, Y-, Z+, Z- directions, respectively.

KRG Relative permeability of the gas phase. Keywords KRGX+, KRGX-, KRGY+, KRGY-, KRGZ+, KRGZ- can be used for directional relative permeabilities in X+, X-, Y+, Y-, Z+, Z- directions, respectively.

KRW Relative permeability of the water phase. Keywords KRWX+, KRWX-, KRWY+, KRWY-, KRWZ+, KRWZ- can be used for directional relative permeabilities in X+, X-, Y+, Y-, Z+, Z- directions, respectively.

ISAT Relative permeability/capillary pressure table pointers.

ISATI Imbibition relative permeability/capillary pressure table pointers.

API API gravity of the liquid phase. Available only when the PVT interpolation option is in use.

TEX Matrix-fracture exchange transmissibility (VIP-DUAL only).

IFT Interfacial tension. Available only when the IFT option is in use.

PHFLAG Phase equilibrium condition, (see GIBBS, Section 8.1.1). Available only when the GIBBS option is in use.

HG Fractional height of gas-oil contact in a block (VE cases only).

HW Fractional height of water-oil contact in a block (VE cases only).

FLOWO Flow of oil out of the 6 faces: negative I, positive I, negative J, positive J, negative K, positive K. Six arrays are written.

6-376 5000.4.4


FLOWG Flow of gas out of the 6 faces: negative I, positive I, negative J, positive J, negative K, positive K. Six arrays are written.

FLOWW Flow of water out of the 6 faces: negative I, positive I, negative J, positive J, negative K, positive K. Six arrays are written.

OIP Total oil volume, surface conditions.

GIP Total gas volume, surface conditions.

WIP Total water volume, surface conditions.

FGIP Free gas volume.

OCIP Condensate in free gas.

TDL -X, +Y diagonal transmissibility including compaction effects, available only with NINEPT option.

TDR +X, +Y direction diagonal transmissibility including compaction effects, available only wth NINEPT option.

PVMUL Pore volume multiplier, ratio of current value to reference value.

PVMULW Water-induced pore volume multiplier, ratio of current value to reference value.

TXMUL X-direction transmissibility multiplier, ratio of current value to reference value.

TYMUL Y-direction transmissibility multiplier, ratio of current value to reference value.

TZMUL Z-direction transmissibility multiplier, ratio of current value to reference value.

TRMUL R-direction transmissibility multiplier, ratio of current value to reference value.

TTMUL Angular direction transmissibility multiplier, ratio of current value to reference value.

5000.4.4 6-377


CN Capillary number. Available only when the VELCTY CN option is in use.

FNDG Non-Darcy gas flow mobility multiplication factor. Available only when the VELCTY NDARCY option is in use.

PTHLD Threshold pressure.

STBDT Maximum IMPES stable timestep size.

SAL Water salinity. Available only when the PVTWSAL tables are entered in VIP-CORE.

The following array names are valid on OUTPUT and MAPOUT cards only in VIP-THERM:

T Temperature.

00 TXT X-direction thermal transmissibility.

00 TYT Y-direction thermal transmissibility.

00 TZT Z-direction thermal transmissibility.

00 TRT R-direction thermal transmissibility.

00 TTT Theta-direction thermal transmissibility.

00 DENW Liquid water phase density.

00 VISW Liquid water phase viscosity.

00 HLOS Heat loss rate.

00 CHLOS Cumulative heat loss.

00 SOR Steam-oil ratio.

00 HOIL Oil phase enthalpy.

00 HGAS Gas phase enthalpy.

00 HWAT Water phase enthalpy.

00 F Flow rate arrays. A FLOWS card must be input in VIP-CORE (VIP-CORE Section 2.2.19.3) in order to print these

arrays. , , and are unit, phase, and

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direction symbols which are specified as

follows. may be omitted to print phase

flows in all directions. and may be omitted to print flows of all phases in all directions

00 = V, N, M for volumetric, molar, or mass flow rate.

00 = O, G, or W for oil, gas, or liquid water phase.

00 = X(R) flow in from i-1 for cartesian (radial) grid.

00 = Y(T) flow in from j-1 for cartesian (radial) grid

00 = Z

00 = E flow in from i+1, j-1 for cartesian grid with 9-point.

00 = W flow in from i-1, j-1 for cartesian grid with 9-point.

param Alpha label on an OUTPUT card causing an action to be taken:

SHFTOG Instructs the program to shift all oil and gas production/injection units by a factor of 1000 for output purposes. For example, cumulative gas production will change from MMSCF to BSCF.

SHFTW Instructs the program to shift all water production/injection units by a factor of 1000 for output purposes. For example, water production rate will change from STB/D to MSTB/D.

TSSUM Causes a timestep summary that includes all timesteps to be printed at the end of the run. FORTRAN Unit 15 is used to store the timestep summary data. Once this keyword is specified it cannot be turned off and is not affected by subsequent OUTPUT cards.

TSSUMG Causes a timestep summary of gas lift usage to be printed at the end of the run.

5000.4.4 6-379


Once this keyword is specified it cannot be turned off and is not affected by subsequent OUTPUT cards.

TSSMFG Causes a timestep summary of flared gas (gas available for reinjection not actually injected) to be printed at the end of the run. Once this keyword is specified it cannot be turned off and is not affected by subsequent OUTPUT cards.

TSSDAT Causes the date instead of the timestep number and the time in days to be printed on the timestep summary at the end of the run. Once this keyword is specified, it cannot be turned off and is not affected by subsequent OUTPUT cards.

WELRPT Causes a report of well status changes to be printed at the end of the run. Once this keyword is specified, it cannot be turned off and is not affected by subsequent OUTPUT cards.

PRFRPT Causes a report of perforation status changes to be printed at the end of the run. Once this keyword is specified, it cannot be turned off and is not affected by subsequent OUTPUT cards.

CPUWMG Causes a report of CPU time within well management to be printed as part of the PRINT SIM simulation statistics report. Once this keyword is specified, it cannot be turned off and is not affected by subsequent OUTPUT cards.

CNVFAIL Causes the detailed iteration summary to be printed when a convergence failure occurs. This option is on unless turned off by use of the CNVFLOFF keyword.

CNVFLOFF Turns off the printing of the detailed iteration summary when a convergence failure occurs.

HCPVTS Causes hydrocarbon-pore-volume-weighted average pressure to be printed in the timestep summaries instead of

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total-pore-volume-weighted average pressure.

WRKRPT Causes an automatic workover report to be printed at the end of the run. Once this keyword is specified, it cannot be turned off and is not affected by subsequent OUTPUT cards.

RCMRPT Causes a report of recompletion unit status changes to be printed at the end of the run. Once this keyword is specified, it cannot be turned off and is not affected by subsequent OUTPUT cards.

PCDON Causes condensate rate and condensate yield to be printed in well, gathering center, flow station, area, field, and well group compositional summaries.

PCDOFF Turns off the printing of condensate rate and condensate yield in well, gathering center, flow station, area, field, and well group compositional summaries.

PCCD Causes cumulative condensate volume to be printed in well, gathering center, flow station, area, field, and well group compositional summaries. Once this keyword is specified, it cannot be turned off and is not affected by subsequent OUTPUT cards.

RCDON Causes condensate rate and condensate yield to be printed in region compositional summary.

RCDOFF Turns off the printing of condensate rate and condensate yield in region compositional summary.

RCCD Causes cumulative condensate volume to be printed in region compositional summary. Once this keyword is specified, it cannot be turned off and is not affected by subsequent OUTPUT cards.

LCDON Causes condensate rate and condensate yield to be printed in well layer compositional summary.

5000.4.4 6-381


LCDOFF Turns off the printing of condensate rate and condensate yield in well layer compositional summary.

NOTE: 1. If a MAP card was specified in VIP-CORE and the MAPOUT card is either omitted or entered with no subsequent keywords, the 4 arrays P, SO, SG, and SW are, by default, written to the map file. In VIP-THERM, T is also written by default.

2. To turn off the writing of any of the arrays listed in this section, specify the card MAPOUT NONE.

3. If the OUTPUT card is omitted or entered with no subsequent keywords, no array reports are printed.

4. All of the alpha labels must appear on one OUTPUT/MAPOUT card. If necessary the continuation character ’>’ can be used.

5. The order of the alpha labels is not significant. All are optional.

6. Each OUTPUT/MAPOUT card supersedes and replaces the previous OUTPUT/MAPOUT card.

7. For output of arrays RS, RV, BOF, BG, GOR, SOR, WCUT, OIP, GIP, FGIP, or OCIP, separator battery assignments must be made for each reservoir region (REGSEP card) except for dead oil runs in VIP-THERM. The calculations for each gridblock use the separator battery defined for the output region to which the gridblock is assigned.

8. The options PCDON, RCDON, LCDON, PCDOFF, RCDOFF, LCDOFF, PCCD, and RCCD are used to specify whether the condensate rates, condensate yields, and cumulative condensate volumes are included in the output of compositional summaries specified by the PRINT card options WELCMP, WLLCMP, GCCMP, FSCMP, ARCMP, REGCMP, FLDCMP, and WGPCMP.These condensate printing options should be selected carefully because they require additional flash calculations which could significantly increase the CPU time. The cumulative well/region condensate volume is zero when the PCCD/RCCN option is first specified unless the CCNDN option is used on the CPLOT card. If the CCNDN option and any of the well, gathering center, flow station, area, or field classes are selected on the CPLOT card, the cumulative well condensate volume is calculated starting from time zero. Likewise, if the CCNDN option and the REGION class are selected on the CPLOT card, the cumulative region condensate volume is calculated starting from time zero.

00 Examples:

00 OUTPUT P SW SGMAPOUT TX SOM DENO

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6.3 Array Print Windows (OUTWINDOW)

00 The OUTWINDOW card is used to specify windows within the grid system for which values of the arrays listed on the OUTPUT, OUTX, OUTY, OUTZ, etc. cards are to be printed.

00 Currently the frequency of array printing is controlled by the PRINT ARRAYS card and each array requested on any of the OUTPUT-type cards is printed in its entirety for every grid. When windows are specified the frequency is still controlled by the PRINT ARRAYS card; for each requested array on the OUTPUT-type cards, all specified windows of gridblock values are printed.

OUTWINDOW

ADDDELETE wname1

(gridname) ii

i2NX

j1j2NY

k1k2NZ

ONLYCHILDRENALSOCHILDREN

wname

.

.

.ENDWINDOW

00 Definitions:

ADD Alpha label indicating that the specified windows are added to the current list. The default is to replace the current list with the specified windows.

DELETE Alpha label indicating that the listed windows are to be removed from the current list. It is an error if no such named window exists. No data cards or ENDWINDOW card may be entered when DELETE is used.

wnamei Alphanumeric name of the window to be deleted from the list. At least one name must be input after the DELETE label.

gridname Name of the grid refinement to which this window applies. If not specified, the window is assumed to apply to the root grid.

Gridblock locations, relative to gridname, are defined by indices I, J, K in reference to the (x, y, z) or (r, , z) grid. The gridblocks contained in the window are those lying in the portion of the grid defined by:

5000.4.4 6-383


i1 I i2

j1 J j2

k1 K k2

00

NX Alpha label indicating that the value of i2 should be set to nx (or nr).

NY Alpha label indicating that the value of j2 should be set to ny (or ntheta).

NZ Alpha label indicating that the value of k2 should be set to nz.

ONLYCHILDREN Alpha label indicating that a window is not created for the blocks in grid gridname, but windows are created for each child grid that exists within this set of blocks. Each window thus created will have the same name.

ALSOCHILDREN Alpha label indicating that, in addition to creating a window in grid gridname, windows are created for each child grid that exists within this set of blocks. Each window thus created will have the same name.

wname Alphanumeric name of this window or set of windows.

ENDWINDOW Alaph label indicating the end of the window data. This card may not be entered if the DELETE data is entered.

NOTE: If neither ONLYCHILDREN nor ALSOCHILDREN is specified, a single window is created.The maximum number of windows is 250.

00 Example:

OUTWINDOWROOT 3 7 2 5 1 NZ WIN1GASCAP 3 NX 3 NY 2 4 WIN2

4 4 7 7 1 NZ ALSOCHILDREN WIN3ENDWINDOW

6-384 5000.4.4


6.4 Content and Frequency of Printed Output (PRINT)

00 The PRINT card allows the user to control the content and frequency of printed output. If the PRINT card is omitted, only the timestep summaries and the simulation statistics report at the end of the run are printed.

PRINT param1 param2 . . . paramn

TIME

TNEXT

OFF

freq

00 Definitions:

param Alpha label of those report(s) being defined:

ITER Detailed iteration summary. For IMPES only, the residuals will not be recomputed after convergence. This is the default.

ITERL Detailed iteration summary. This option forces the residuals to be recomputed after convergence.

WELLS Well production summary and well injection summary.

WSTRM Include in the TSFM surface facility report the compositions of various production streams for each well. The facility report is automatically printed whenever PRINT WELLS is active and only if the TSFM surface facility model option is in use.

REGIONS Region report. To compute fluids-in-place the hydrocarbon moles in each region are flashed to the surface.

REGBLK Region report. To compute fluids-in-place the hydrocarbon moles in each gridblock are flashed to the surface. The surface quantities are summed over the regions. This is the method used by VIP-CORE to compute initial fluids-in-place.

REGOG Region report. Same as REGIONS except that reservoir oil and gas

5000.4.4 6-385


compositions are printed instead of total compositions and total moles for each phase are added.

REGBOG Region report. Same as REGBLK except that reservoir oil and gas compositions are printed instead of total compositions and total moles for each phase are added.

ARRAYS Array reports.

SEP Separator battery report, with compositional and volumetric information at all stages and at surface conditions.

SEPS Short form of the separator battery report, with information only for surface conditions.

FIELD Field production and injection summaries. In addition to the field production and injection reports, a report of production by pressure system will be printed if predictive well management is active.

WLLYR Well production and injection summaries detailed by layers for active wells only. Also controls the plot records written; i.e., only the layers for active wells are written to the plot file. Also controls the special layer output reports for WBSIM runs.

WLLYRS Well production and injection summaries, detailed by layers for all wells. Also controls the plot records written; i.e., the layers for all wells are written to the plot file. Also controls the special layer output reports for WBSIM runs.

WLGRP Well production and injection summaries, for well groups defined by the user (see the WLGRP card for details).

WLHIS Well production and injection histories written to FORTRAN Unit 40.

6-386 5000.4.4


GCLYR Gathering center production and injection summaries detailed by layers.

FSLYR Flow station production and injection summaries detailed by layers.

ARLYR Area production and injection summaries detailed by layers.

FLLYR Field production and injection summaries detailed by layers.

WLPOT Well potential production summary and well potential injection summary.

FLPOT Field potential production summary and field potential injection summary.

WELCMP Well production and injection compositional summaries.

WLLCMP Well production and injection compositional summaries detailed by well perforations.

GCCMP Gathering center production and injection compositional summaries.

FSCMP Flow station production and injection compositional summaries detailed by gathering centers.

ARCMP Area production and injection compositional summaries detailed by gathering centers.

REGCMP Region production and injection compositional summaries.

FLDCMP Field production and injection compositional summaries detailed by gathering centers.

WGPCMP Well group production and injection compositional summaries detail by wells.

RFT Well RFT report. For vertical wells the report includes gridblock information for each layer. For deviated wells this information is printed only for each perforation.

5000.4.4 6-387


RFTFILE Well RFT report written to FORTRAN Unit 18.

FACUTL Facility utilization summary. Information will be printed for any well management entity for which production targets were specified.

FACFIL Facility utilization summary written to FORTRAN Unit 57.

MGOR Marginal gas-oil ratio report. Available only if the PREDICT MGOR option has been specified.

SIM Simulation statistics. This report is automatically printed at the end of the run. The report includes time simulated, timestep information, and, when available, CPU information for the current run and for cumulative simulation runs.

TSSUM Timestep summary report. This parameter is used to control the frequency of entries in the timestep summary report produced at the end of the run.

SSSUM Spread sheet summary report written to FORTRAN Units 72-77. The files to be written and the quantities written on each file are controlled by the SSSUM card.

SSSUMR Same as SSSUM except that each time a file is written, it is rewound and the header, if requested, is written at the top.

WLSUM Well production and injection summaries detailed by layers written to FORTRAN Unit 1

TRACK Tracking output on FORTRAN unit 17.

TRACKW Water tracking report.

FLUX Boundary flux summaries.

TIME Alpha label that causes all reports named on this card to be printed each time a TIME or DATE card is

6-388 5000.4.4


encountered. Default is not to print on the basis of TIME or DATE cards.

TNEXT Alpha label that causes all reports named on this card to be printed only the next time a TIME or DATE card is encountered. Default is not to print on the basis of the next TIME or DATE card.

OFF Alpha label that causes all reports named on this card to not be printed. It is equivalent to specifying a frequency of 99999.to

freq A number that causes reports named on this card to be printed after every freq timesteps (each timestep cut counts as one timestep). Default is 99999.

NOTE: 1. At least one of the report labels given above must appear on the PRINT card. If a report label appears on more than one PRINT card, the frequency specified on the last PRINT card applies.

2. At least one of the values, TIME, TNEXT, OFF, or freq, must appear after the report label(s) on the card. Either TIME or TNEXT may appear with freq, but not with each other.

3. Different frequencies of printing can be used for each report label.

4. Any number of PRINT cards may appear in any data group.

5. If an ARRAYS label is specified on the PRINT card, but no array names are specified on an OUTPUT card, then no array reports are printed.

6. For the RFT/RFTFILE reports the OUTRFT card must be used to specify the wells to be included.

7. For compositional summaries (i.e., the WELCMP, WLLCMP, GCCMP, FSCMP, ARCMP, REGCMP, FLDCMP, and WGPCMP options), the user can use the options PCDON, RCDON, LCDON, PCDOFF, RCDOFF, LCDOFF, PCCD, and RCCD on the OUTPUT card to specify whether the condensate rates, condensate yields, and cumulative condensate volumes will be included in the output.

8. Three additional output reports will be printed when using the WBSIM option. These are all printed at the same frequency as the PRINT WLLYR report. These include: [1] an output table at the start of the timestep containing the effective wellbore permeability for the step, Moody friction factor, mixture density, delta-P friction, phase velocities, critical velocities [minimum gas flow velocities to lift insitu liquids], Reynold’s numbers, and alpha and beta parameters for all of the wellbore segments, [2] an output table at the end of the timestep for the wellbore perforations, showing the production/injection rates and gas-oil ratios and water cuts, production and injection cumulatives, and reservoir and wellbore pressures, and [3]

5000.4.4 6-389


an output table presenting a profile of all of the wellbore segments, containing the insitu saturations, average densities and viscosities, alpha and beta flow parameters, effective wellbore permeabilities, and wellbore pressures.

00 Examples:

00 PRINT REGION TIME

6.5 Buildup Pressure Output Control (BUILDUP)

00 The BUILDUP option is designed to allow the user to simulate the effects of shutting in a well without actually shutting it in.

00 This option cannot be used for producers with rate specified with QMULT.

BUILDUP wl time1 ... timencomp1 ... compngrad1 ... gradn

00 Definitions:

wl List of wells for which buildup data is specified (see Section 1.5.2).

time Time in hours for shut in.

comp Total compressibility of fluids and formation near the well, psi-1 (kPa-1). A value of zero causes the compressibility to be computed internally. The compressibility comp is given by

comp = cr + Soco + Sgcg + Swcw ,

where cr, co, cg, and cw are the compressibilities of rock, oil, gas, and water, respectively, and So, Sg, and Sw are oil, gas, and water saturations, respectively.

grad Average gradient of fluids in the well measured in the field, psi/ft (gm/cc). A value of zero causes the gradient to be computed internally.

00 This option computes and writes to a formatted results file corrected buildup pressures for wells. This information is written on Fortran unit 30. The calculation of buildup pressure in multi-layered wells is based on a development of the Peaceman equations. When a BUILDUP card appears in a recurrent data group, the requested information will be output at the time corresponding to the next

6-390 5000.4.4


TIME or DATE card only. Buildup pressure is calculated for each perforated layer in requested wells at the shut in time specified by the user. The number of time, comp and grad values must equal the number of wells in the well list.

00 In field tests a single buildup pressure is measured for a well, not for each perforation. Therefore, a single buildup pressure must be obtained from the layer values. There is no unique weighting method to determine the single buildup-pressure value. The weighting scheme adopted here is the production-rate-weighted buildup pressure.

00 Note that the total compressibility and the density should be the estimated values obtained in the field during the buildup test. Users should be cautious in using the default values computed by the simulator.

6.6 Write Files (WPLOT, WMAP, WMAPOLD, WREST, WFLUX, WFILE, WCPLOT)

writef

TIME

TNEXT

OFF

freq

00 writef can be one of the following:WPLOT, WMAP, WMAPOLD, WREST, WFLUX, WFILE, WCPLOT

00 Definitions:

TIME Alpha label that causes the appropriate file or record to be written each time a TIME or DATE card is encountered. Default is not to write on the basis of TIME or DATE cards.

TNEXT Alpha label that causes the appropriate file or record to be written only the next time a TIME or DATE card is encountered. Default is not to write on the basis of the next TIME or DATE card.

OFF Alpha label that causes the appropriate file or record to not be output. It is equivalent to specifying a frequency of 99999.

freq A number that causes the appropriate file or record to be written after every freq timesteps (each timestep cut counts as one timestep). Default is 99999.

5000.4.4 6-391


WPLOT The WPLOT card controls the writing of data to the vdb file or to the plot file (FORTRAN Unit 11) that can be used to plot the production/injection performance of individual wells, well management levels, regions, and the field. These plots are generated by a plotting program that is separate from VIP-EXECUTIVE. WPLOT can only be used if a PLOT card was included in the utility data.

WMAP The WMAP card invokes the writing of array data to the vdb file or to the map file (FORTRAN Unit 27). Maps of this array data are generated by a program that is separate from VIP-EXECUTIVE. WMAP can only be used if a MAP card was included in the initialization data.

WMAPOLD The WMAPOLD card invokes the writing of SIMOUT map files on FORTRAN Unit 9 (output of selected array data). Maps of this array data are generated by a program that is separate from VIP-EXECUTIVE. WMAPOLD can only be used if a MAPOLD card was included in the initialization data.

WREST The WREST card controls the writing of restart records on FORTRAN Unit 2. If no WREST cards are used, no user-specified restart records are written during the recurrent portion of the simulation. A restart record is automatically written after initialization.

WFLUX The WFLUX card controls the writing of a file, on FORTRAN Unit 16, that contains boundary flux data for input into a subsequent simulation model. WFLUX can only be used if a FLUX card was included in the initialization data.

WFILE The WFILE card controls the writing of a special well file to FORTRAN Unit 71.

WCPLOT The WCPLOT card controls the writing of data to the vdb file or to the cplot file (FORTRAN Unit 26) that can be used to plot the production/injection compositional performance of individual wells, well management levels, regions, and the field. These plots are generated by a plotting program that is separate from VIP-EXECUTIVE. WCPLOT can only be used if a CPLOT card was included in the initialization data.

NOTE: At least one of the values, TIME, TNEXT, OFF, or freq, must appear on the writef card. Either TIME or TNEXT may appear with freq.Files will not be saved unless the appropriate commands are added to the

6-392 5000.4.4


job control stream. Information is only written out to the appropriate file when one of the writef commands is encountered.

00 Examples:

00 To write data out to the PLOT file at every TIME (or DATE card) and every 30 timesteps:

00 WPLOT TIME 30

6.7 Save Temporary Restarts (WLASTR)

WLASTR

TIME

TNEXT

OFF

freq

00 Definitions: As defined for WREST (Section 6.6).

NOTE: The WLASTR option writes restart records according to the time or frequency specified retaining only the last restart record written, essentially to provide a recovery mechanism for jobs that terminate abnormally due to time limits, etc. It supplements rather than replaces the restart records written as a result of the WREST card(s).At each time a restart record is written, if the previous restart record was a temporary one (one written by a WLASTR card) it is first removed before the current restart record is written.Restart records written by a WLASTR card do not replace ones written by WREST cards.

6.8 Write Fluid Tracking Data (WTRACK)

WTRACK (INPLACE)

TIME

TNEXT

OFF

freq

00 Definitions:

INPLACE Alpha label indicating that reservoir in-place tracked fluid moles should also be written to the file.

5000.4.4 6-393


TIME Alpha label that causes a record to be written each time a TIME or DATE card is encountered. Default is not to write records on the basis of TIME or DATE cards.

TNEXT Alpha label that causes a record to be written only the next time a TIME or DATE card is encountered. Default is not to write records on the basis of the next TIME or DATE card.

OFF Alpha label that causes the record not to be output. It is equivalent to specifying a frequency of 99999.

freq A number that causes records to be written after every freq timesteps (each timestep cut counts as one timestep). Default is 99999.

NOTE: The WTRACK card controls the writing of fluid tracking results into a separate file. WTRACK can only be used if a TRACK card was included in the initialization data.At least one of the values, TIME, TNEXT, OFF, or freq, must appear on the WTRACK card. Either TIME or TNEXT may appear with freq.Tracking records are written on FORTRAN Unit 17, but may not be saved unless the appropriate commands are added to the job control stream.If no WTRACK cards are used, no tracking records are written.

6-394 5000.4.4


6.9 Print/Map Mole Fractions (OUTX, OUTY, OUTZ, OUTXT, OUTYT, OUTZT, MAPX, MAPY, MAPZ, MAPXT, MAPYT, MAPZT)

outf cmpid1 cmpid2 ... cmpidk

00 outf can be one of the following:OUTX, OUTY, OUTZ, OUTXT, OUTYT, OUTZTMAPX, MAPY, MAPZ, MAPXT, MAPYT, MAPZT

00 Definitions:

cmpid Alpha label identifying a component whose mole fractions will be included in the array reports/map file. Only those components named will be printed/mapped.

OUTX Print liquid mole fractions.

OUTY Print vapor mole fractions.

OUTZ Print overall hydrocarbon mole fractions.

OUTXT Print tracked liquid mole fractions.

OUTYT Print tracked vapor mole fractions.

OUTZT Print tracked overall hydrocarbon mole fractions.

MAPX Map liquid mole fractions.

MAPY Map vapor mole fractions.

MAPZ Map overall hydrocarbon mole fractions.If the diffusion option is on (Section 8.11), diffusion fluxes for the specified component will also be mapped. See the Diffusion chapter in the VIP-CORE Reference Manual for more information.

MAPXT Map tracked liquid mole fractions.

MAPYT Map tracked vapor mole fractions.

MAPZT Map tracked overall hydrocarbon mole fractions.

NOTE: 1. If the user wishes to print/map arrays of mole fractions, they must explicitly select the components to be output on one of the above cards.

5000.4.4 6-395


2. When the tracked mole fraction arrays are requested, the order of printing is: all requested components for tracked fluid 1, all requested components for tracked fluid 2, etc.

3. In VIP-THERM, H2O may be specified for cmpid on the OUTY, OUTYT, MAPY, or MAPYT cards for the water mole fraction in the vapor phase.

6.10 Format of Mole Fraction Array Print (ALLCOMP)

00 The ALLCOMP card is used to specify how mole fraction arrays (selected with OUTX, OUTY, OUTZ, OUTXT, OUTYT, OUTZT) are to be printed. The default mode is to print each component of a mole fraction array individually. When ALLCOMP is specified, all requested components of a mole fraction array (e.g. liquid mole fraction) are printed in a vertical column for each gridblock.

ALLCOMP ON

OFF

00 Definitions:

ON Alpha label indicating that all requested components of a mole fraction array are printed in a vertical column for each gridblock. This is the default if neither ON nor OFF is specified.

OFF Alpha label indicating that all requested components of a mole fraction array are printed individually. This is the default when no ALLCOMP card is entered.

6.11 Tracked Water Type Fractions (OUTWT, MAPWT)

OUTWT tknamw1 tknamw2... tknamwkMAPWT tknamw1 tknamw2... tknamwn

00 Definitions:

tknamw Alpha label identifying the tracked water type for which the fractional saturations of that fluid will be included in the array reports/map file. Only those tracked water types named will be printed/mapped.

6-396 5000.4.4


6.12 Specify Which Separator Batteries to Process (OUTSEP)

00 The user may control the amount of output produced by the program for separator battery reports by specifying which batteries should be processed. If no battery designation follows the OUTSEP label, no battery report will be printed.

OUTSEP ibat

ALL

DEFidfbat

ALL

00 Definitions:

ibat List of user-defined separator batteries. No VIP-CORE generated default separator batteries can be specified here.

ALL Alpha label indicating that reports for all user-defined separator batteries should be generated.

DEF Alpha label indicating that the remaining data on the OUTSEP card apply to default separator batteries.

idfbat List of default separator batteries. A value of -npvt, where npvt is the number of a PVT table (VIP-ENCORE) or npvt is 1 (VIP-COMP), will cause the use of one of the default separator batteries defined by VIP-CORE.

ALL Alpha label indicating that reports for all default separator batteries should be generated.

NOTE: Each OUTSEP card supersedes and replaces the previous OUTSEP card.

00 Example:

00 OUTSEP 1

5000.4.4 6-397


6.13 Reservoir Region Separator Battery Assignment (REGSEP)

00 The REGSEP card is used to assign separator batteries to output regions for surface volume calculations. If the number of separators is increased for this run, then a REGSEP card will be required to handle region assignment.

00 In order to calculate surface volumes to be included in region reports, VIP-EXECUTIVE must have a separator battery assignment for each reservoir region. The battery assignments are also needed if the arrays RS, GOR, WCUT, OIP, GIP, FGIP, or OCIP are to be printed or mapped.

REGSEP ibat1...ibatnreg

00 Definitions:

ibat Separator battery number for each output region. Alternatives include the battery number of a separator input in the separator data (Surface Separation Data), a value of -npvt which accesses a default separator, and a value of 0:

ibati = nbat (input battery)= -npvt (default separator)= 0

A value of 0 will result in the default value -1 being used for surface volume calculations in VIP-CORE, and no surface volumes will be reported for that region report in the simulation modules.

nreg Maximum output region number defined in the IREGION data.

NOTE: REGSEP data is passed from VIP-CORE to the simulation module, but under certain circumstances the value may be changed. If a default separator battery was specified in VIP-CORE, and REGSEP is not input in the simulation module, then the value from VIP-CORE will be changed to 1 if Separator 1 has been input or -1 if Separator 1 has not been input. If any other default separator is desired for a region, then the REGSEP card must be specified in the simulation module. To specify a default separator ibat should be set to -npvt, where npvt is a PVT table number (VIP-ENCORE) or npvt is 1 (VIP-COMP).

6-398 5000.4.4


6.14 Compute Potentials for Plot File (PLOTPTN)

00 The PLOTPTN card controls whether well and well management level potential production and injection rates are computed for inclusion in the plot file. If PLOTPTN ON has not been specified, the 5 potential rate variables in the plot files will have value zero.

PLOTPTN

ON

OFF

00 Definitions:

ON Alpha label indicating potential production and injection rates are to be included in the plot files.

OFF Alpha label indicating potential production and injection rates are to show as zeroes in the plot files. This is the default.

6.15 Printout Processed Well Cards (PRINTOUT)

00 The PRINTOUT card controls the printout of the processed well and table data cards.

PRINTOUT

ON

OFF

00 Definitions:

ON Alpha label indicating all processed recurrent data cards are to be printed. This is the default.

OFF Alpha label indicating that the printing of well and tabular data will be suppressed.

5000.4.4 6-399


6.16 Logical Unit for Timestep Summary Output (IPRTSS)

00 The IPRTSS card is used to define the FORTRAN logical unit onto which the end-of-run timestep summary output will be written. This summary output is identical to the timestep summary in the main output file and is controlled by the TSSUM and TSSDAT keywords on the OUTPUT card and the TSSUM keyword on the PRINT card.

IPRTSS iunit

00 Definition:

iunit FORTRAN logical unit number for the timestep summary report. Default is to not write this summary to a file.

NOTE: The user should specify a unit number that is not used for another file.

6.17 Specify Wells Included in Well RFT Report (OUTRFT)

00 The OUTRFT card is used to specify the wells to be included in the well RFT report (RFT or RFTFILE on the PRINT card).

OUTRFT wl

00 Definition:

wl List of wells for which an RFT report will be generated.

NOTE: Each OUTRFT card supersedes and replaces the previous OUTRFT card.

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6.18 Spreadsheet Files (SSSUM)

00 The SSSUM card is used to specify options and variables to appear in the spreadsheet summary files. By specifying separate SSSUM cards, a spreadsheet summary file may be obtained for each of the following: field, area, flow station, gathering center, well, region, node. The FORTRAN units used are, respectively, Unit 72, Unit 73, Unit 74, Unit 75, Unit 76, Unit 77, Unit 80. All variables that are plotted can be written to be the spreadsheet summary files. The frequency of the output is controlled by the SSSUM parameter on the PRINT card.

00 The member number, time, and member name are automatically written in the first three fields of each requested spreadsheet file.

00 A maximum of 50 variables may be written to any spreadsheet summary file.

00 Information for the node spreadsheet file may be found in Section 10.18.2, “Node Spreadsheet File (SSSUM)”.

00 The optional SSSID card is used to specify an alphanumeric run identification label, up to eight characters, which can be written to the spreadsheet files as specified by the RUNID keyword. This label is useful when spreadsheet data from different runs are combined in a single file by the user. This option is only available in VIP-THERM.

(SSSID sssid)

SSSUM

FIELD

AREA

FLOSTA

GATHER

WELL

REGION

NODE

(TAB)(HEADER)(RUNID) varnm1 varnm2 ... varnmn

00 Definitions:

Alpha label indicating the spreadsheet summary file to which the subsequent data applies:

FIELD Field.

AREA Area.


5000.4.4 6-401



WELL Well.

REGION Output region.

NODE Node.

TAB Alpha label indicating that the columns will be separated by a tab character. Omission will result in columns separated by a comma.

HEADER Alpha label indicating that a title line, column header line, and a units line should be included in the file at each time.

RUNID Alpha label indicating that the run identification label specified on the SSSID card will be written as a column in the spreadsheet file. Available only in VIP-THERM.

varnm Alpha label specifying one or more of the following variables:

The following may be used for any of the files:

DATE Calendar date.

TSNUM Timestep number.

QGP Gas production rate.

QOP Oil production rate.

QWP Water production rate.

QGI Gas injection rate.

QWI Water injection rate.

CGP Cumulative gas production.

COP Cumulative oil production.

CWP Cumulative water production.

CGI Cumulative gas injection.

CWI Cumulative water injection.

RESVOL Reservoir production/injection:

1. Reservoir oil production rate.2. Reservoir gas production rate.

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3. Reservoir water production rate.4. Reservoir gas injection rate.5. Reservoir water injection rate.6. Cumulative reservoir oil produced.7. Cumulative reservoir gas produced.8. Cumulative reservoir water produced.9. Cumulative reservoir gas injected.10. Cumulative reservoir water injected.

The following may be used for any file except REGION:

GLG Gaslift gas injection rate.

CGLG Cumulative gaslift gas injection.

MGOR Marginal gas-oil ratio.

POTQGP Gas potential production rate.

POTQOP Oil potential production rate.

POTQWP Water potential production rate.

POTQGI Gas potential injection rate.

POTQWI Water potential injection rate.

OGR Oil-gas ratio.

WGR Water-gas ratio.

WCUT Water cut.

GOR Gas-oil ratio.

WOR Water-oil ratio.

SAL Water salinity.

TWPi Production rate of tracked water type i, i=1 .. number of tracked water types. A separate variable is entered for each requested type (e.g., TWP4 TWP12).

CTWi Cumulative production of tracked water type i, i=1 .. number of tracked water types. A separate variable is entered for each requested type (e.g., CTW4 CTW12).

TWIi Injection rate of tracked water type i, i=1 .. number of tracked water types. A

5000.4.4 6-403


separate variable is entered for each requested type (e.g., TWI4 TWI12).

CTIi Cumulative injection of tracked water type i, i=1 .. number of tracked water types. A separate variable is entered for each requested type (e.g., CTI4 CTI12).

TWFi Concentration in produced water of tracked water type i, i=1 .. number of tracked water types; i.e., production rate of tracked water type i divided by water production rate. A separate variable is entered for each requested type (e.g., TWF4 TWF12).

The following may be used for FIELD or REGION only:

TPVP Total PV-weighted average pressure.

HCPVP Hydrocarbon PV-weighted average pressure.

HCPVPD HCPV-weighted average pressure at datum.

GIP Gas-in-place.

OIP Oil-in-place.

WIP Water-in-place.

OREC Percent oil recovery.

GREC Percent gas recovery.

AQNFLX Water influx from analytical aquifers.

PZ P/Z (Equal to P in VIP-THERM).

The following may be used for WELL only:

PERF1P Gridblock pressure of first perforation.

PAVE Mobility-weighted average well pressure.

BHP Well bottomhole pressure.

THP Well tubinghead pressure.

DRDWNP Well average drawdown pressure.

6-404 5000.4.4


BLDP Well buildup pressure.

ONTIME Ontime factor.

DAYSP Days well has produced.

DAYSI Days well has injected.

PLFS TSFM plant liquid flow stream.

CPLFS TSFM cumulative plant liquid flow stream.

PRGAS TSFM plant residual gas.

CPRGAS TSFM cumulative plant residual gas.

EQWL TSFM equivalent total wellstream.

CEQWL TSFM cumulative equivalent total wellstream.

GCNAME Name of gathering center to which well belongs.

GCNUM Number of gathering center to which well belongs.

RCMUNT Active recompletion unit number.

The following may be used for WELL or GATHER only:

FSNAME Name of the flow station to which well/gathering center belongs.

FSNUM Number of the flow station to which well/gathering center belongs.

The following may be used for WELL, GATHER, or FLOSTA only:

ARNAME Name of area to which well/gathering center/flow station belongs.

ARNUM Number of areas to which well/gathering center/flow station belongs.

The following may be used for GATHER, FLOSTA, AREA, or FIELD only:

WELLS Number of active:

5000.4.4 6-405


1. Total wells.2. Producers.3. Gaslift producers.4. Water injectors.5. Gas injectors.

NGL From the NGLPLANT:

1. Feed rate.2. Liquid rate.3. Vapor rate.4. Cumulative produced.

LPG From the LPGPLANT:


MI From the MIPLANT:


GSHNDL Gas handling quantities:

1. Shrinkage gas rate.2. Fuel gas rate.3. Sales gas rate.4. Makeup gas rate.5. Available injection gas rate.6. Makeup fuel gas rate.7. Flared gas rate (FIELD only).8. Cumulative shrinkage gas.9. Cumulative fuel gas.10. Cumulative sales gas.11. Cumulative makeup gas.12. Cumulative flared gas (FIELD only).

The following may be used for FIELD or AREA only:

GFO Gas field operations (single or multiple contracts):

1. DCQ.2. ACQ.3. Potential gas production rate.4. Gas sales rate.

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5. Cumulative sales gas.6. Number of cycles in first pass.

varnm Additional alpha labels specifying variables valid in VIP-THERM only:

The following may be used for any of the files:

QEP Energy production rate.

QSTP Steam production rate.

QRLP Reservoir liquid production rate.

QEI Energy injection rate.

CEP Cumulative energy production.

CSTP Cumulative steam production.

CRLP Cumulative reservoir liquid production.

CEI Cumulative energy injection.

The following may be used for FIELD or REGION only:

EIP Energy in place.

STIP Steam in place.

QHL Heal loss rate.

CHL Cumulative heat loss.

PVSI Pore volumes steam injected.

PVOP Pore volumes oil produced.

FIOP Fraction of initial oil produced.

The following may be used for REGION only:

QRGP Reservoir gas production rate.

QROP Reservoir oil production rate.

QRWP Reservoir water production rate.

QRSP Reservoir steam production rate.

QRGI Reservoir gas injection rate.

QRWI Reservoir H2O injection rate.

5000.4.4 6-407


CRGP Cumulative reservoir gas production.

CROP Cumulative reservoir oil production.

CRWP Cumulative reservoir water production.

CRSP Cumulative reservoir steam production.

CRGI Cumulative reservoir gas injection.

CRWI Cumulative reservoir H2O injection.

QBGP Boundary reservoir gas outflow rate.

QBOP Boundary reservoir oil outflow rate.

QBWP Boundary reservoir water outflow rate.

QBSP Boundary reservoir steam outflow rate.

QBEP Boundary energy outflow rate.

QBGI Boundary reservoir gas inflow rate.

QBOI Boundary reservoir oil inflow rate.

QBWI Boundary reservoir water inflow rate.

QBSI Boundary reservoir steam inflow rate.

QBEI Boundary Energy inflow rate.

CBGP Cumulative boundary reservoir gas outflow.

CBOP Cumulative boundary reservoir oil outflow.

CBWP Cumulative boundary reservoir water outflow.

CBSP Cumulative boundary reservoir steam outflow.

CBEP Cumulative boundary energy outflow

CBGI Cumulative boundary reservoir gas inflow.

CBOI Cumulative boundary reservoir oil inflow.

6-408 5000.4.4


CBWI Cumulative boundary reservoir water inflow.

CBSI Cumulative boundary reservoir steam inflow.

CBEI Cumulative boundary energy inflow.

NOTE: 1. All of the alpha labels must appear on one SSSUM card. If necessary the continuation character ’>’ can be used.

2. One and only one of the FIELD, AREA, FLOSTA, GATHER, WELL, or REGION labels must be specified.

3. Except for TAB and HEADER, the order of the alpha labels is the order the variables will appear in the file.

4. The member number, simulation time, and member name are automatically written in the first three fields of the file.

5. Each SSSUM card for a specific level (FIELD, etc) supersedes and replaces the previous SSSUM card for that level.

6. A FLOWS card must be input in the initialization utility data in order to write the region boundary rates and cumulatives (QB* and CB*) in VIP-THERM.

00 Example:

00 SSSUM WELL TAB HEADER DATE QOP BHPSSSUM FIELD HEADER TAB DATE COP PZ

5000.4.4 6-409


6.19 Well Average Pressure Calculation (OUTPAVG)

00 The OUTPAVG card is used to specify the method for computing the well average pressure in the production/injection summaries and output to the plot file. The choices are mobility-weighted datum pressure average or one of several patterns.

OUTPAVG STDorOUTPAVG PATTERN

ACTIVE

ALL DATUM

GRIDBLOCK iptn

orOUTPAVG PATTERN

ACTIVE

ALL DATUM

GRIDBLOCK (card 1)

iptn1 . . . iptnNZ (card 2)orOUTPAVG WELL

ACTIVE

ALL DATUM

GRIDBLOCK w1 (card 1)

iptn1 . . . iptnn (card 2)

00 Definitions:

STD Alpha label indicating that the mobility-weighted datum pressure average is to be computed. This is the default.

PATTERN Alpha label indicating one of the possible patterns is to be used to compute the well average pressure.

ACTIVE Alpha label indicating that only active perforations are used in the calculation. This is the default.

ALL Alpha label indicating that all perforations, including inactive or shut-in perforations, are used in the calculation.

DATUM Alpha label indicating that the well average datum pressure is to be computed. This is the default for a pattern calculation.

GRIDBLOCK Alpha label indicating that the well average gridblock pressure is to be computed.

6-410 5000.4.4


WELL Alpha label indicating that a pattern is being assigned to each well in the well list.

wl List of wells for which iptn values are being specified (see Section 1.5.2).

iptn Pattern type:

1 Square pattern of size 1 gridblock by 1 gridblock

2 5-spot pattern

3 Square pattern of size 3 gridblocks by 3 gridblocks




0 Exclude this layer from the calculation.

NOTE: 1. In the second format, the iptn pattern will be used for each block in the calculation for every well.

2. The third format may only be used in a single grid model (i.e., no DECOMPOSE allowed).

3. In the fourth format, the number of iptn values must equal the number of wells in the well list.

4. Only gridblocks in the same grid as the perforation will be included in the average calculation.

5. No coarsened block is allowed in the pattern calculation. If one exists, the STD method will be used for the well.

6. Each OUTPAVG PATTERN card supersedes and replaces the previous OUTPAVG PATTERN card.

7. It is allowed to enter both OUTPAVG WELL and OUTPAVG PATTERN data that would apply to the same well. The OUTPAVG WELL data will be used.

8. A pattern for each perforation may be entered on the FPERF card by using the keyword PATTERN.

5000.4.4 6-411


6.20 Print Well Indices (PRWI)

00 The PRWI card causes an immediate printout of the well index for each well.

PRWI

6.21 Print Well Properties Summary (PRWSTA)

00 The PRWSTA card causes an immediate printout of the well properties for each well.

PRWSTA

6.22 Track File Format (TFORM)

00 The TFORM card is used to control the format of fluid tracking results file, the writing of which is controlled by the WTRACK card.

TFORM [FORM][BINARY]

00 Definitions:

TFORM Keyword indicating that the track file format is to be specified. If the TFORM card is omitted, formatted records are written to the track files (.trk and .tps files).

FORM Keyword indicating that formatted records are to be written to the track files.

BINARY Keyword indicating that binary records are to be written to the track files.

NOTE: The TFORM card should appear only once (before the first DATE or TIME card) in each restart run, and different formats may be specified for successive restart runs. Since this information is stored in the restart record, this card needs only appear once (at time zero) if the same format is to be used throughout the entire simulation.

00 Examples:

00 C TO SPECIFY BINARY TRACK FILES

6-412 5000.4.4


TFORM BINARY

6.23 Boundary Flux File Format (FXFORM)

FXFORM [FORM][BINARY]

00 Definitions:

FORM Alpha label indicating that a formatted flux file is to be written or read-in. This is the default.

BINARY Alpha label indicating that a binary flux file is to be written or read-in.

NOTE: The FXFORM card specifies either formatted or binary flux file is to be written (in the output mode of the boundary flux option) or read-in (input mode of the boundary flux option).

00 Examples:

C***** Boundary Flux File FormatFXFORM BINARY

6.24 Print by Cross-Sections (CROSS)

00 The CROSS card causes arrays to be printed by cross-sections (vertical planes), instead of by areal planes. This card is necessary only if the user wishes to change the printout from what was used in VIP-CORE.

CROSS

ONOFF

00 Definitions:

ON Alpha label indicating that arrays are to be printed by cross-sections (vertical planes). This is the default if neither ON nor OFF is specified.

OFF Alpha label indicating that arrays are to be printed by areal planes.

5000.4.4 6-413


6.25 Grouping Wells (WLGRP)

00 The WLGRP card is used to define well groups which are used for reporting purposes and/or for easily setting maximum well rates. The well group report will be printed when the keyword WLGRP is included on the PRINT card. The QMAXGR card (see following section) is used to set the maximum rate for all wells in a group.

WLGRP grpnum (grpnam)wl

00 Definitions:

grpnum Group number.

grpnam Group name of up to eight (8) characters. The first character in the name must be alphabetic unless the name is immediately preceded by the character #.

wl List of wells belonging to the group. If the group number is equal to zero, then the well numbers included in the well list are removed from all well groups.

NOTE: Well groups can be formed or modified by means of new WLGRP cards. At least one WLGRP card should be included for each group. This card specifies the group number, the group name, and the list of wells belonging to the group. Each well can belong to only one group. If a well was included in one group and then it is included in a second group, this well is automatically deleted from the first group. If several WLGRP cards are included with the same group number, then all wells specified in these cards will belong to one group. To remove a well from the group, the number of this well should be included in the WLGRP card with a zero group number.

00 Examples:

00 In this example, the names GROUP_1 and GROUP_2 are assigned to Group 1 and Group 2. Initially Wells 25, 26, 29, 2, 6, and 12 are included in Group 1 and Wells 27, 28, and 30 are included in Group 2. Then Well 29 is removed from Group 1, Well 31 is added to Group 2, and Well 26 is moved from Group 1 to Group 2.

00 WLGRP 1 GROUP_125 26 29WLGRP 12 6 12WLGRP 2 GROUP_2

6-414 5000.4.4


00 27 28 30PRINT WLGRP TIME.........DATE 1 7 1987WLGRP 029WLGRP 226, 31

6.26 Group Specification of Maximum Well Rates (QMAXGR)

00 The QMAXGR card used to set the maximum well rates for all wells in a well group defined with the WLGRP card. The QMAX and QMAXGR cards are order-dependent.

QMAXGR grp qmaxgr

00 Definitions:

00 grp Group name or group number.

qmaxgr Maximum well rate to assign to each of the wells in the well group. For each well the unit of this rate depends on the well’s type. That is, whatever unit would have applied on the QMAX card applies here.

6.27 Plot File Well Specification (PLOTLIST)

00 The PLOTLIST card is used to specify which wells are to be included in the well plot file and/or the well layer plot file.

PLOTLIST WELLWLLYR

ON

OFF ALL

wl

00 Definitions:

WELL Alpha label indicating that the data on this card applies to the well plot file.

WLLYR Alpha label indicating that the data on this card applies to the well layer plot file.

5000.4.4 6-415


ON Alpha label indicating that the specified wells are to be included in the plot file.

OFF Alpha label indicating that the specified wells are to be excluded from the plot file.

ALL Alpha label indicating that the data on this card applies to all wells.

wl List of wells to which the data on this card applies (see Section 1.5.2).

NOTE: 1. If the PLOTLIST card is not entered, all wells are included in the plot file.2. To restrict the wells on the plot file, all wells must first be excluded (OFF), then the desired wells included (ON).

00 Example:

00 PLOTLIST WELL OFF ALLPLOTLIST WELL ON D*

6-416 5000.4.4


6.28 Spreadsheet Well Specification (SPRLIST)

00 The SPRLIST card is used to specify which wells are to be included in the well spreadsheet file, and, possibly, in what order.

00 The SPRLIST card may also be used to specify nodes for the node spreadsheet file (see Section 10.18.3).

SPRLIST WELL

ON

OFFORDER

ORDEROFF

ALLwl

00 Definitions:

WELL Alpha label indicating that the data on this card applies to the well spreadsheet file.

ON Alpha label indicating that the specified wells are to be included in the spreadsheet file. If an active ordered list currently exists and a well does not already exist in the list, it will be appended.

OFF Alpha label indicating that the specified wells are to be excluded from the spreadsheet file.

ORDER Alpha label indicating that a new ordered list of wells is being created. Only these wells will be written.

ORDEROFF Alpha label indicating that the order option is turned off. No wells will be output to the spreadsheet file until turned on by a subsequent SPRLIST card.Since ORDEROFF excludes all wells automatically, neither the keyword ALL nor a list of wells need be entered.

ALL Alpha label indicating that the data on this card applies to all wells.

wl List of wells to which the data on this card applies (see section 1.5.2).

NOTE: 1. If the SPRLIST card is not entered, all wells are included in the spreadsheet file.

2. To restrict the wells on the spreadsheet file, all wells must first be excluded (OFF), then the desired wells included (ON).

5000.4.4 6-417


00 Example:

00 SPRLIST WELL OFF ALLSPRLIST WELL ON PROD*

6-418 5000.4.4


6.29 Saturation Endpoint Debug Report (SATDEBUG)

00 The SATDEBUG card is used to create a file named <casename>.satdebug containing, for each requested active gridblock, unscaled and scaled saturation endpoint values. Also included for each gridblock are tables of relative permeability and capillary pressure values for approximately 20 saturations spanning the range of 0 to maximum saturation.

00 To create the report for each active gridblock in the model, use the format:

SATDEBUG

00 To specify the ranges of active gridblocks to include in the report, use the format:

SATDEBUG BLOCKS (NOCASCADE)i1 i2 j1 j2 k1 k2 (gridname)(data card may be repeated as necessary)

00 Definitions:

BLOCKS Alpha label indicating that only gridblocks in the following ranges are to be included in the report.

NOCASCADE Alpha label indicating that gridblocks in lower level grids are not to be automatically included in the report.

i1, i2 Gridblock range in the x direction.

j1, j2 Gridblock range in the y direction.

k1, k2 Gridblock range in the z direction.


NOTE: The report will only be generated once per run. Any subsequent specification of the SATDEBUG card will be ignored.

00 Examples:

00 C ***** SATURATION ENDPOINT DEBUG REPORTSATDEBUG BLOCKS68 78 1 1 5 10 LGR15 5 12 15 2 2 LGR2

5000.4.4 6-419


6.30 Results File Formats

00 The PLOT, CPLOT and MAP files written out by VIP-EXECUTIVE can be post-processed by a variety of programs. To facilitate user access to these files, the content and formats are described below. Each line corresponds to a different record. The "Type" column specifies the variable type for each field in the record. The "Format" column specifies the format used to write the record to a formatted file.

00 The meanings of the symbols in the "Type" column are:

C*4 CHARACTER*4C*6 CHARACTER*6C*8 CHARACTER*8C*20 CHARACTER*20C*80 CHARACTER*80I INTEGERR REAL

6.30.1 Plot File Organization

Once, at top of file 00

Type Format Record

C*6 10A6 PLOT <FORM | BIN> 1.1.1 <simulator><simulator version> [DUAL]C*20 2A20 <casename><case parent>C*80 A80 <title1>C*80 A80 <title2>C*80 A80 <title3>I 10I5 <# classes> <day> <month> <year> <nx> <ny> <nz> <# comps>C*8 10A8 <class #1 name> <class #2 name> ...I 10I5 <# variables in class #1> <# variables in class #2> ...

Loop for each classC*4 18A4 TIME <variable #1 name> <variable #2 name> ...

end loop for class

Repeated for each requested timeData for each class is output only if requested 00

Type Format Record

WELL ClassC*8 A8 WELLR 5G15.5 <timestep #> <time> <# wells> <max # wells> 1

Loop for each wellC*8 8A8 <well name> <well #> 0 <1st perf i><1st perf j><gc #><fs #><area #>R 1P6E13.6 <variable #1 value> < variable #2 value> ...

end loop for well

6-420 5000.4.4


WLLYR ClassC*8 A8 WLLYRR 5G15.5 <timestep #> <time> <# wells> <max # wells> <max # perfs>

Loop for each wellC*8 8A8 <well name><well #><# perfs><1st perf i><1st perf j><gc#><fs #><area #>

Loop for each perfC*8 2A8 <perf gridblock #> <layer name>R 1P6E13.6 <variable #1 value> <variable #2 value> ...

end loop for perfend loop for well

GATHER Class

C*8 A8 GATHERR 5G15.5 <timestep #> <time> <# gathering centers> <max # gc’s> 1

Loop for each gathering centerC*8 8A8 <gc name> <gc #> 0 0 0 <gc #> <fs #> <area #>R 1P6E13.6 <variable #1 value> <variable #2 value> ...

end loop for gathering center

FLOSTA ClassC*8 A8 FLOSTAR 5G15.5 <timestep #> <time> <# flow stations> <max # fs’s> 1

Loop for each flow stationC*8 8A8 <fs name> <fs #> 0 0 0 0 <fs #> <area #>R 1P6E13.6 <variable #1 value> <variable #2 value> ...

end loop for flow station

AREA ClassC*8 A8 AREAR 5G15.5 <timestep #> <time> <# areas> <max # areas> 1

Loop for each areaC*8 8A8 <area name> <area #> 0 0 0 0 0 <area #>R 1P6E13.6 <variable #1 value> <variable #2 value> ...

end loop for area

REGION ClassC*8 A8 REGIONR 5G15.5 <timestep #> <time> <# regions> <max # regions> 1

Loop for each regionC*8 8A8 <region name> <region #> 0 0 0 0 0 0R 1P6E13.6 <variable #1 value> <variable #2 value> ...

end loop for region

FIELD ClassC*8 A8 FIELDR 5G15.5 <timestep #> <time> 1 1 1 C*8 8A8 FIELD 1 0 0 0 0 0 0R 1P6E13.6 <variable #1 value> <variable #2 value> ...C*8 A8 STOP (only at end-of-file)

5000.4.4 6-421


NOTE: See the PLOT card in Utility Data for a list of valid Class names. The current set of variable names can be obtained from the example below.Well Pressures written to the PLOT file depend on parameters set during the run. By default, PTOP is the pressure of the top perforated block, PAVE is a mobility weighted block pressure at datum (mobility of the well production/injection phase) and BHP is the bottomhole flowing pressure at datum (DRDN is (PAVE-BHP)). The datum depth defaults to the depth of the first equilibration region, but can be set with a BHP or THP card. These pressures are modified by the OUTPAVG and BUILDUP cards. In contrast, all layer pressures are at depth.The variables beginning with the character "?" denote temporary positions in the plot file. These may be used for future development without changing the size of the plot records.

00 Examples:

00 Plot File - Based on "PLOT ALL FILE"

PLOT FORM 5.0.0 EXEC v1998rTESTVIP TEST MODEL EXAMPLE FOR DOCUMENTATION PURPOSES 7 1 1 1992 18 6 3 3WELL WLLYR GATHER FLOSTA AREA REGION FIELD 39 25 26 25 27 23 35TIMEQGP QOP QWP QGI QWI CGP COP CWP CGI CWI PTOPPAVEBHP THP DRDNPBLDQGLGCGLGDYSPDYSIMGORPLF CPLFPRG CPRGETW CETWPQGPPQOPPQWPPQGIPQWIOGR WGR ?TM1?TM2?TM3?TM4?TM5TIMEIX JY KZ QOP QGP QWP GOR WC PRESPDATBHP QGI QWI ROP RGP RWP RGI RWI DTOPDBOTPLOSPWDPPLENPANVPANATIMEQGP QOP QWP QGI QWI CGP COP CWP CGI CWI CGV QGLGCGLGMGORPQGPPQOPPQWPPQGIPQWIOGR WGR ?TM1?TM2?TM3?TM4?TM5TIMEQGP QOP QWP QGI QWI CGP COP CWP CGI CWI QGLGCGLGMGORPQGPPQOPPQWPPQGIPQWIOGR WGR ?TM1?TM2?TM3?TM4?TM5TIMEQGP QOP QWP QGI QWI CGP COP CWP CGI CWI QGLGCGLGMGORPQGPPQOPPQWPPQGIPQWIOGR WGR QSG CSG ?TM1?TM2?TM3?TM4?TM5TIMECGP COP CWP CGI CWI PAVDPAVTPAVHGIP OIP WIP QOP QGP QWP QGI QWI OGR WGR ?TM1?TM2?TM3?TM4?TM5TIMEQGP QOP QWP QGI QWI CGP COP CWP CGI CWI PAVTPAVHGIP OIP WIP QGLGCGLGMGORP/Z PQGPPQOPPQWPPQGIPQWIOGR WGR ORECGRECQSG CSG ?TM1?TM2?TM3?TM4?TM5WELL 14.000 274.00 3.0000 20.000 1.0000 PRD 8 0 5 2 1 1 1 1.280376E+02 5.242931E+02 9.459076E+01 0.000000E+00 0.000000E+00 3.521548E+04 1.439770E+05 2.142366E+04 0.000000E+00 0.000000E+00 2.724752E+03 2.693599E+03 2.453844E+03 0.000000E+00 2.397549E+02 0.000000E+00 0.000000E+00 0.000000E+00 2.740000E+02 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 4.094837E+03 7.387733E+01 0.000000E+00 0.000000E+00

6-422 5000.4.4


0.000000E+00 0.000000E+00 0.000000E+00 INJ1 1 0 3 3 1 1 1 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 5.495544E+02 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 1.422169E+05 2.819950E+03 2.750626E+03 2.837861E+03 0.000000E+00-8.723476E+01 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 2.740000E+02 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00INJ6 6 0 3 3 1 1 1 0.000000E+00 0.000000E+00 0.000000E+00 2.594420E+02 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 6.894230E+04 0.000000E+00 2.775718E+03 2.760035E+03 2.761008E+03 0.000000E+00-9.733106E-01 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 2.740000E+02 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00WLLYR 14.000 274.00 3.0000 20.000 100.00 INJ1 1 1 3 3 1 1 1 255 K3 3.000000E+00 3.000000E+00 3.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 2.819950E+03 2.750626E+03 2.907185E+03 0.000000E+00 5.495544E+02 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 5.557241E+02 5.754000E+03 5.780000E+03 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00INJ6 6 1 3 3 1 1 1 39 K1 3.000000E+00 3.000000E+00 1.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 2.775718E+03 2.760035E+03 2.776692E+03 2.594420E+02 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 2.778621E+02 0.000000E+00 5.700000E+03 5.727000E+03 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00PRD 8 2 5 2 1 1 1 23 K1 5.000000E+00 2.000000E+00 1.000000E+00 2.913259E+02 7.329747E+01 2.062178E+01 2.515996E+02 6.610653E-02 2.724752E+03 2.686124E+03 2.492472E+03 0.000000E+00 0.000000E+00 3.322876E+02 0.000000E+00 2.085887E+01 0.000000E+00 0.000000E+00 5.700000E+03 5.733000E+03 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 131 K2 5.000000E+00 2.000000E+00 2.000000E+00 2.329666E+02 5.474043E+01 7.396899E+01 2.349711E+02 2.409918E-01 2.754788E+03 2.703844E+03 2.504788E+03 0.000000E+00 0.000000E+00 2.639768E+02 0.000000E+00 7.481309E+01 0.000000E+00 0.000000E+00 5.733000E+03 5.766000E+03 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00GATHER 14.000 274.00 1.0000 5.0000 1.0000 1 0 0 0 1 1 1 1.943243E+03 7.093291E+03 1.114112E+03 2.594420E+02 3.353396E+03 5.335137E+05 1.943689E+06 2.220256E+05 6.894230E+04 8.946251E+05 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 3.650234E+03 5.733261E+01 0.000000E+00 0.000000E+00 0.000000E+00

5000.4.4 6-423


0.000000E+00 0.000000E+00FLOSTA 14.000 274.00 1.0000 5.0000 1.0000 1 0 0 0 0 1 1 1.943243E+03 7.093291E+03 1.114112E+03 2.594420E+02 3.353396E+03 5.335137E+05 1.943689E+06 2.220256E+05 6.894230E+04 8.946251E+05 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 3.650234E+03 5.733261E+01 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00AREA 14.000 274.00 1.0000 5.0000 1.0000 1 0 0 0 0 0 1 1.943243E+03 7.093291E+03 1.114112E+03 2.594420E+02 3.353396E+03 5.335137E+05 1.943689E+06 2.220256E+05 6.894230E+04 8.946251E+05 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 3.650234E+03 5.733261E+01 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00REGION 14.000 274.00 1.0000 1.0000 1.0000 1 0 0 0 0 0 0 5.332544E+05 1.944172E+06 2.220256E+05 6.894230E+04 8.946251E+05 2.651545E+03 2.661513E+03 2.658203E+03 1.711230E+07 6.371604E+07 3.296248E+07 7.094940E+03 1.942356E+03 1.114112E+03 2.594420E+02 3.353396E+03 3.116205E+00 3.051307E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00FIELD 14.000 274.00 1.0000 1.0000 1.0000 FIELD 1 0 0 0 0 0 0 1.943243E+03 7.093291E+03 1.114112E+03 2.594420E+02 3.353396E+03 5.335137E+05 1.943689E+06 2.220256E+05 6.894230E+04 8.946251E+05 2.661513E+03 2.658203E+03 1.711230E+07 6.371604E+07 3.296248E+07 0.000000E+00 0.000000E+00 0.000000E+00 2.860177E+03 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 3.650234E+03 5.733261E+01 3.116205E+00 3.051307E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00STOP

6.30.2 Compositional Plot File Organization

Once, at top of file 00

Type Format Record

C*6 10A6 PLOT <FORM | BIN> 5.0.0 <simulator><simulator version> [DUAL]C*20 2A20 <casename><case parent>C*80 A80 <title1>C*80 A80 <title2>C*80 A80 <title3>I 10I5 <# classes> <day> <month> <year> <nx> <ny> <nz> <# comps>C*8 10A8 <class #1 name> <class #2 name> ...I 10I5 <# variables in class #1> <# variables in class #2> ...

Loop for each classC*4 18A4 TIME <variable #1 name> <variable #2 name> ...

end loop for class

6-424 5000.4.4


Repeated for each requested timeData for each class is output only if requested 00

Type Format Record

WELL ClassC*8 A8 WELLR 5G15.5 <timestep #> <time> <# wells> <max # wells> 1

Loop for each wellC*8 8A8 <well name> <well #> 0 <1st perf i><1st perf j><gc #><fs #><area #>R 1P6E13.6 <variable #1 value> < variable #2 value> ...

end loop for wellWLLYR Class

C*8 A8 WLLYRR 5G15.5 <timestep #> <time> <# wells> <max # wells> <max # perfs>

Loop for each wellC*8 8A8 <well name><well #><# perfs><1st perf i><1st perf j><gc#><fs #><area #>

Loop for each perfC*8 2A8 <perf gridblock #> <layer name>R 1P6E13.6 <variable #1 value> <variable #2 value> ...

end loop for perfend loop for well

GATHER Class

C*8 A8 GATHERR 5G15.5 <timestep #> <time> <# gathering centers> <max # gc’s> 1

Loop for each gathering centerC*8 8A8 <gc name> <gc #> 0 0 0 <gc #> <fs #> <area #>R 1P6E13.6 <variable #1 value> <variable #2 value> ...

end loop for gathering center

FLOSTA ClassC*8 A8 FLOSTAR 5G15.5 <timestep #> <time> <# flow stations> <max # fs’s> 1

Loop for each flow stationC*8 8A8 <fs name> <fs #> 0 0 0 0 <fs #> <area #>R 1P6E13.6 <variable #1 value> <variable #2 value> ...

end loop for flow station

AREA ClassC*8 A8 AREAR 5G15.5 <timestep #> <time> <# areas> <max # areas> 1

Loop for each areaC*8 8A8 <area name> <area #> 0 0 0 0 0 <area #>R 1P6E13.6 <variable #1 value> <variable #2 value> ...

end loop for area

REGION ClassC*8 A8 REGION

5000.4.4 6-425


R 5G15.5 <timestep #> <time> <# regions> <max # regions> 1Loop for each region

C*8 8A8 <region name> <region #> 0 0 0 0 0 0R 1P6E13.6 <variable #1 value> <variable #2 value> ...

end loop for region

FIELD ClassC*8 A8 FIELDR 5G15.5 <timestep #> <time> 1 1 1 C*8 8A8 FIELD 1 0 0 0 0 0 0R 1P6E13.6 <variable #1 value> <variable #2 value> ...C*8 A8 STOP (only at end-of-file)

NOTE: See the CPLOT card in uility data for a list of valid Class names. The current set of variable names can be obtained from the example below.

00 Examples:

00 Cplot File - Based on "CPLOT ALL FILE"

PLOT FORM 5.0.0 EXEC v1998r TESTVIP TEST MODEL EXAMPLE FOR DOCUMENTATION PURPOSES 7 1 1 1992 18 6 3 3WELL WLLYR GATHER FLOSTA AREA REGION FIELD 21 14 21 21 21 21 21TIMEQ1P Q2P Q3P C1P C2P C3P X1P X2P X3P Y1P Y2P Y3P Q1I Q2I Q3I C1I C2I C3I QCDPYCDPCCDPTIMEQ1P Q2P Q3P X1P X2P X3P Y1P Y2P Y3P Q1I Q2I Q3I QCDPYCDPTIMEQ1P Q2P Q3P C1P C2P C3P X1P X2P X3P Y1P Y2P Y3P Q1I Q2I Q3I C1I C2I C3I QCDPYCDPCCDPTIMEQ1P Q2P Q3P C1P C2P C3P X1P X2P X3P Y1P Y2P Y3P Q1I Q2I Q3I C1I C2I C3I QCDPYCDPCCDPTIMEQ1P Q2P Q3P C1P C2P C3P X1P X2P X3P Y1P Y2P Y3P Q1I Q2I Q3I C1I C2I C3I QCDPYCDPCCDPTIMEQ1P Q2P Q3P C1P C2P C3P X1P X2P X3P Y1P Y2P Y3P Q1I Q2I Q3I C1I C2I C3I QCDPYCDPCCDPTIMEQ1P Q2P Q3P C1P C2P C3P X1P X2P X3P Y1P Y2P Y3P Q1I Q2I Q3I C1I C2I C3I QCDPYCDPCCDP WELL 14.000 274.00 3.0000 20.000 1.0000 PRD 8 0 5 2 1 1 1 3.405392E+02 2.014404E+02 6.630428E+02 9.365748E+04 5.532673E+04 1.820668E+05 1.112212E-02 2.304266E-01 7.584513E-01 9.841481E-01 3.693783E-03 1.215812E-02 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00INJ1 1 0 3 3 1 1 1 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00

6-426 5000.4.4


0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00INJ6 6 0 3 3 1 1 1 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 5.450015E+02 1.021878E+02 3.406259E+01 1.448249E+05 2.715467E+04 9.051556E+03 0.000000E+00 0.000000E+00 0.000000E+00WLLYR 14.000 274.00 2.0000 20.000 100.00 INJ6 6 1 3 3 1 1 1 39 K1 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 5.450015E+02 1.021878E+02 3.406259E+01 0.000000E+00 0.000000E+00PRD 8 2 5 2 1 1 1 23 K1 1.947711E+02 1.122778E+02 3.679337E+02 1.112236E-02 2.312086E-01 7.576690E-01 9.840874E-01 3.720505E-03 1.219207E-02 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 131 K2 1.457680E+02 8.916255E+01 2.951092E+02 1.112182E-02 2.294493E-01 7.594289E-01 9.842236E-01 3.660599E-03 1.211581E-02 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00 0.000000E+00GATHER 14.000 274.00 1.0000 5.0000 1.0000 1 0 0 0 1 1 1 5.145818E+03 2.819694E+03 8.822700E+03 1.412639E+06 7.732170E+05 2.416716E+06 1.112383E-02 2.394468E-01 7.494294E-01 9.829879E-01 4.237121E-03 1.277496E-02 5.450015E+02 1.021878E+02 3.406259E+01 1.448249E+05 2.715467E+04 9.051556E+03 0.000000E+00 0.000000E+00 0.000000E+00FLOSTA 14.000 274.00 1.0000 5.0000 1.0000 1 0 0 0 0 1 1 5.145818E+03 2.819694E+03 8.822700E+03 1.412639E+06 7.732170E+05 2.416716E+06 1.112383E-02 2.394468E-01 7.494294E-01 9.829879E-01 4.237121E-03 1.277496E-02

5000.4.4 6-427


5.450015E+02 1.021878E+02 3.406259E+01 1.448249E+05 2.715467E+04 9.051556E+03 0.000000E+00 0.000000E+00 0.000000E+00AREA 14.000 274.00 1.0000 5.0000 1.0000 1 0 0 0 0 0 1 5.145818E+03 2.819694E+03 8.822700E+03 1.412639E+06 7.732170E+05 2.416716E+06 1.112383E-02 2.394468E-01 7.494294E-01 9.829879E-01 4.237121E-03 1.277496E-02 5.450015E+02 1.021878E+02 3.406259E+01 1.448249E+05 2.715467E+04 9.051556E+03 0.000000E+00 0.000000E+00 0.000000E+00REGION 14.000 274.00 1.0000 1.0000 1.0000 1 0 0 0 0 0 0 5.145818E+03 2.819694E+03 8.822700E+03 9.051556E+03 0.000000E+00 0.000000E+00 1.112475E-02 2.394976E-01 7.493776E-01 9.834299E-01 4.013149E-03 1.255697E-02 5.450015E+02 1.021878E+02 3.406259E+01 1.448249E+05 2.715467E+04 9.051556E+03 0.000000E+00 0.000000E+00 0.000000E+00FIELD 14.000 274.00 1.0000 1.0000 1.0000 FIELD 1 0 0 0 0 0 0 5.145818E+03 2.819694E+03 8.822700E+03 1.412639E+06 7.732170E+05 2.416716E+06 1.112383E-02 2.394468E-01 7.494294E-01 9.829879E-01 4.237121E-03 1.277496E-02 5.450015E+02 1.021878E+02 3.406259E+01 1.448249E+05 2.715467E+04 9.051556E+03 0.000000E+00 0.000000E+00 0.000000E+00STOP

6.30.3 Map File Organization

VIP-CORE 00

Type Format Record

C*6 10A6 MAP <FORM | BIN> 1.0.1 <simulator><simulator version> [DUAL]C*80 A80 <title1>C*80 A80 <title2>C*80 A80 <title3>I 8I5 2 <day><month><year><nx><ny><nz><# comps>R G15.5 <inner radius for radial model; 0. otherwise>C*8 2A8 INIT RECURRI 2I5 <# of INIT arrays> <# of RECURR arrays>C*4 18A4 <INIT array #1 name><INIT array #2 name> ...C*4 18A4 <RECURR array #1 name><RECURR array #2 name> ...C*8 10A8 <component #1 name> <component #2 name> ...C*8 A8 INITR 3G15.5 0 0.0 <# of INIT arrays>

Loop for each INIT arrayR 1P6E13.6 <array value i> , i = 1, ..., number of gridblocks

end loop for INIT arrayC*8 A8 STOP

6-428 5000.4.4


Simulation Modules - Repeated for each requested time 00

Type Format Record

C*8 A8 RECURRR 3G15.5 <timestep #><time><# of RECURR arrays>

Loop for each RECURR arrayR 1P6E13.6 <array value i>, i = 1, ..., number of gridblocks

end loop for RECURR arrayC*8 A8 WLOCR 3G15.5 <timestep #><time><number of perforations>

Loop for each perforationI 3I5 <well number><perforation status><gridblock number>

end loop for perforationC*8 A8 STOP (only at end-of-file)

NOTE: Perforation Status values are as follows0Shut in1Gas Injector2Water Injector3Solvent Injector4Producer

00 Examples:

00 CORE Map File Format -Based on "MAPOLD P SG SW FORM"

MAP FORM 1.0.1 CORE v1998r VIP TEST MODEL EXAMPLE FOR DOCUMENTATION PURPOSES 2 1 1 1992 18 6 3 3 .00000E+00INIT RECURR 54 3DX DY DZ DEP DZN POR KX KY KZ ISATIPVTIEQUTMX TMY TMZ ?FX ?FY DXB DYB DZB DZBNMDEPPVR TXR TYR TZR MLTXMLTYMLTZP SG SW SWM PSATSO SOM PDATX1 Y1 Z1 X2 Y2 Z2 X3 Y3 Z3 PV TX TY TZ API KH GOC WOC P SG SW LIGHT HEAVY1 HEAVY2 INIT .00000E+00 .00000E+00 54.000 6.220000E+02 6.220000E+02 6.220000E+02 6.220000E+02 6.220000E+02 6.220000E+02 ..... .....STOP

5000.4.4 6-429


00 EXEC Map File Format - Based on "MAPOLD P SG SW FORM"

RECURR .00000E+00 .00000E+00 3.0000 2.952821E+03 2.952821E+03 2.952821E+03 2.953362E+03 2.953904E+03 2.953904E+03 2.951562E+03 2.940778E+03 2.933616E+03 2.926477E+03 2.924697E+03 2.922384E+03..........WLOC .00000E+00 .00000E+00 .00000E+00RECURR 14.000 274.00 3.0000 2.760746E+03 2.757746E+03 2.762810E+03 2.761857E+03 2.756173E+03 2.758267E+03 2.753419E+03 2.737406E+03 2.730219E+03 2.720897E+03 2.715025E+03 2.713665E+03..........WLOC 14.000 274.00 4.0000 8 4 23 8 4 131 1 2 255 6 1 39STOP

6-430 5000.4.4


6.30.4 Hydrocarbon Track File Organization

00 The hydrocarbon track file is written by the simulation modules. Information in a track file is organized in the form of records. There are three types of records: the header record, the production time record, and the in-place time record. The frequency of output of these records is controlled through use of the WTRACK card.

Header Record - Written only once at time = 0. 00

Type Format Record

I 4I10 <# tracked fluids> <max # wells> <max # gc’s> <# comps>C*80 A80 <title1> <title2> <title3>C*6 10A6 <tracked fluid #1 name> <tracked fluid #2 name> ...I 3I5 <day> <month> <year>R*8,I F12.3,I10 0.0 <number of gridblocks>R*8 8E15.7 <flag array value i>, i = 1, ..., number of gridblocksR*8 8E15.7 <initial gas saturation value i>, i = 1, ..., number of gridblocks

In-Place Time Record - Repeated for each requested time 00

Type Format Record

C*8 A8 IN PLACER*8,I F12.3,I10 <time> <number of gridblocks>

Loop for each gridblockC*6,I A6,I5 BLOCK <gridblock number>

Loop for each tracked fluidR*8 8E15.7 <tracked gas mole fraction value i>, i = 1, ..., # components

End loop for tracked fluidR*8 8E15.7 <gas mole fraction value i>, i = 1, ..., # components

Loop for each tracked fluidR*8 8E15.7 <tracked total mole fraction value i>, i = 1, ..., # components

End loop for tracked fluidR*8 8E15.7 <total mole fraction value i>, i = 1, ..., # components

End loop for gridblockR*8 8E15.7 <gas saturation value i>, i = 1, ..., number of gridblocks

5000.4.4 6-431


Well Production Time Record - Repeat for each requested time Output if NOWELL has not been specified with TRACK card. 00

Type Format Record

C*8 A8 WELLSR*8,I F12.3,I10 <time> <# wells>

Loop for each wellC*4,I A4,I5 WELL <well #>





End loop for well

Production Time Record - Repeated for each requested time 00

Type Format Record

C*8 A8 GATHERR*8,I F12.3,I10 <time> <# gc’s>

Loop for each gathering centerC*4,I A4,I5 GC <gc #>





End loop for gathering center

6-432 5000.4.4

Chapter

7

00000Simulator Control

7.1 Timestep Control

00 VIP-EXECUTIVE moves the reservoir model through a succession of timesteps. The interval of time between states is called the “timestep.” Within each timestep the simulator performs “outer iterations,” that is, Newton iterations, to resolve the non-linear changes in pressures and saturations which may occur over the timestep. In most cases “inner iterations” are performed within each outer iteration to iteratively solve the linearized system of equations for the changes in reservoir variables between successive Newton steps. (If the direct linear solver is used, then no inner iterations are required.)

00 VIP-EXECUTIVE can select its own timesteps. They are constrained only by (1) the maximum changes in reservoir variables specified on the DT card, or (2) by gridblock throughput limitations when the IMPES formulation is used (see IMPSTAB card). Timestep size is altered automatically to hit exactly the times or dates on TIME or DATE cards. Under automatic timestep control maximum pressure, saturations, vapor fraction, and total composition changes sometimes are exceeded slightly to save the work required to repeat the timestep.

00 The number of outer iterations (Newton steps) performed during a timestep is governed by the ITNLIM, TOLD, and TOLR cards. The TOLD and TOLR cards establish two sets of criteria for convergence of a timestep. The TOLD card specifies one set of convergence criteria based on the maximum changes in the primary unknowns over the last Newton step. Convergence of the outer iterations

over a timestep is achieved when none of the changes in P, S, (Sw), V (Sg),

or Z which occurred during the previous iteration are larger in absolute value than the corresponding tolerances established on the TOLD card. A second set of tests for convergence is defined by the TOLR cards. When the material balance error for each phase in each gridblock is less than the tolerances specified on the TOLR card, the conservation equations are assumed to have been solved and the timestep is concluded. The TOLD tests are independent of the TOLR tests. Either set of convergence tests can signal convergence of the timestep even if the other has not yet been satisfied. The ITNLIM card specifies the minimum and maximum number of outer iterations to be used for a timestep, as well as bounding limits for the maximum changes in the primary unknowns for any Newton step. Should any of these limits be exceeded, VIP-EXECUTIVE will damp the entire solution vector, such that the reduced changes now honor the

5000.4.4 7-433


maximum changes specified on the DT card, and then perform another outer iteration. For this reason, an excessively small value for any of the iteration limits slows or even prevents convergence. Failure to converge the outer iterations of a timestep within itnmax outer iterations will normally cause the timestep to be repeated. A timestep will also be repeated if the tolerances on the DT card are exceeded, if the maximum changes are being checked (see the optional second line following the DT card below).

7.1.1 Timestep Controls (DT)

00 The DT card defines the timestep size and the maximum changes allowed during the timestep.

DT dt dtmin dtmax dpmax (dtmpmx) dsmax dvmax dzmax (dtswmx)(card 1)

BOTH

DTONLY

MAXONLY

NONE p

BOTH

DTONLY

MAXONLY

NONE T BOTH

DTONLY

MAXONLY

NONEs

BOTH

DTONLY

MAXONLY

NONE v

BOTH

DTONLY

MAXONLY

NONE z

BOTH

DTONLY

MAXONLY

NONE

t

(card 2)

00 Definitions:

dt Timestep size, days. A negative value triggers the use of automatic timestep control. Here, the next timestep is +dt in length; thereafter, the program chooses timestep size within user constraints. Omit the remaining variables on this card if dt is positive.

dtmin Minimum timestep size, days. Default is 1 day.

dtmax Maximum timestep size, days. Default is 100 days.

dpmax Maximum pressure change allowed during a time-step, psia (kPa). Default is 300 psia for the IMPES formulation; 500 psia for the implicit formulation.

dtmpmx Maximum temperature change allowed during a timestep, °F(°C). Default is 100°F. Enter only in VIP-THERM.

dsmax Maximum saturation change allowed during a timestep using the IMPES formulation. Maximum change in water saturation allowed during a timestep using the implicit formulation. Default is 0.03 for the IMPES formulation; 0.1 for the implicit formulation.

dvmax Maximum change in vapor fraction allowed during a timestep using the IMPES formulation. Maximum

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change in gas saturation allowed during a timestep using the implicit formulation. Default is 0.04 for the IMPES formulation; 0.1 for the implicit formulation.

dzmax Maximum change in total mole fraction allowed during a timestep. Default is 0.03 for the IMPES formulation; 0.1 for the implicit formulation.

dtswmx Maximum tracked water saturation change allowed during a timestep. Default is 0.1.

BOTH Alpha label indicating that the appropriate maximum will be used for both checking the maximum change over the timestep and timestep size calculation. This is the default for a problem using the IMPES formulation.

DTONLY Alpha label indicating that the appropriate maximum will be used for timestep size calculation only. The maximum change check will be ignored. This is the default for a problem using the implicit formulation.

MAXONLY Alpha label indicating that the appropriate maximum will be used for checking the maximum change over the timestep only. The timestep size calculation will ignore this constraint.

NONE Alpha label indicating that the appropriate maximum will be ignored completely.

NOTE: 1. The DT card may contain dt only, all values through dpmax, all values through dzmax, or all values. No other combinations are allowed.

2. A value of zero may be input for dt. At time = 0, this causes the first timestep to be of size dtmin and subsequent timestep sizes to be under automatic timestep control. At time > 0, the timestep size calculation remains under automatic timestep control, allowing the user to change the other parameters without having to set the timestep size.

3. Timestep size is altered automatically to coincide exactly to the times or dates specified on TIME and DATE cards, even when fixed timesteps are used.

4. Under automatic timestep control the maximum pressure, saturation, vapor fraction (gas saturation) and composition changes specified on the DT card are sometimes exceeded by a small amount to save the work required to repeat the timestep. If they are exceeded by a large amount (MAXOVR card), the timestep will be repeated. The maximum number of timesteps cuts is three by default, but it may be respecified using the TCUT card.

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5. Card 2 is an optional card that allows the user to control when the maximum constraints will be used. The data is order dependent; e.g., if an alpha is needed for dvmax, then one must also be specified for dpmax and dsmax.

6. The optional last parameter can be specified to enable timestep control as a function of the maximum changes in the saturation of any of the tracked water types. This parameter will be used in the timestep size calculation only, and will not result in a timestep cut-back if its value is exceeded during a timestep.

7.1.2 Timestep Size After Rate Changes (DTQMAX)

00 The DTQMAX card defines the timestep size to use for the first timestep following well rate changes (QMAX/QMULT cards).

DTQMAX dtqmax

00 Definition:

dtqmax Timestep size to be used for the first timestep following the input of rate changes (QMAX/QMULT cards), days.

NOTE: 1. The value of dtqmax will apply only if automatic timestep control is on.

2. If no dtqmax value is input, or if a value less than or equal to 0 is specified, automatic timestep size selection will be used.

3. If a DT card is entered at the same time as rate changes, the value of dt on that card will be honored.

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7.1.3 Outer Iteration Controls (ITNLIM)

ITNLIM itnmin itnmax (dplim) (dtlim) (dswlim) (dvlim) (dzlim)

00 Definitions:

itnmin Minimum number of outer iterations per timestep required before convergence is allowed. Default is 1.

itnmax Maximum number of outer iterations per timestep. Failure to converge will normally cause the timestep to be repeated. Default is 10.

dplim Maximum pressure change allowed during any single outer iteration, psia (kPa). Default is 450 psia for the IMPES formulation; 750 psia for the implicit formulation.

dtlim Maximum temperature change allowed during any single outer iteration, °F(°C). Default is 150°F. Enter only in VIP-THERM.

dswlim Maximum change in water saturation allowed during any single outer iteration. Default is 0.045 for the IMPES formulation; 0.15 for the implicit formulation.

dvlim Maximum change in vapor fraction allowed during any single outer iteration using the IMPES formulation. Maximum change in gas saturation allowed during any single outer iteration using the implicit formulation. Default is 0.06 for the IMPES formulation; 0.15 for the implicit formulation.

dzlim Maximum change in total composition allowed during any single outer iteration using the IMPES formulation. Maximum change in primary phase composition allowed during any single outer iteration using the implicit formulation. Default is 0.045 for the IMPES formulation; 0.15 for the implicit formulation.

NOTE: For each of the maximum changes on this card, if the value is not entered but the corresponding maximum change is entered on the DT card, then the default value is set to the product of the value on the DT card and MAXOVR (MAXOVR card).

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7.1.4 Control Convergence Failures and Timestep Cuts (TCUT)

00 The TCUT card is used to control simulator treatment of convergence failures and timestep cuts.

TCUTnfails

OFFnctol

00 Definitions:

nfails Maximum number of convergence failures permitted during a single timestep. Default is 3.

OFF Alpha label that causes the simulator to ignore convergence failures.

nctol Maximum number of timestep cuts for any reason permitted during a single timestep. Default is 3.

NOTE: 1. After each convergence failure the timestep size is cut by a factor of 2 and the timestep is retried, if OFF was not specified.

2. After nctol-1 timestep cuts in a single timestep, the timestep size is set equal to dtmin (see DT card).

3. If a convergence failure occurs for a timestep size of dtmin, an additional attempt is made using a timestep size of 0.1*dtmin.

4. If more than nfails convergence failures (or possibly nfails+1; see note 3) or more than nctol timestep cuts occur during a single timestep, the run is terminated and a restart record is written at the end of the last successful timestep.

5. The keyword OFF causes the simulator to ignore convergence failures in determining the acceptability of a timestep. The result of the timestep will be accepted (subject to the tolerances on the DT card) without regard to the inadequate closure of the material balance equations. This will frequently lead to poor material balances in the model.

6. If it was not already printed, an iteration summary will be printed for a timestep that has a convergence failure unless the CNVFLOFF keyword has been specified on the OUTPUT card.

00 Example:

00 TCUT 10 10

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7.1.5 Control Treatment of IMPES Stability (IMPSTAB)

00 The IMPSTAB card is used to control simulator treatment of IMPES stability restrictions. By default, the simulator calculates the maximum timestep size for which IMPES is a stable formulation (based on volumetric and molar throughput) and forces the timestep to be no larger than this value.

IMPSTAB (V98)

ststar

OFF

ON

stslim NOCUTS

mxstsc FLOWIN

00 Definitions:

V98 Alpha label that causes the version 98 algorithm to be used.

ststar Fraction of the maximum stable IMPES timestep to use as the target for each calculation of timestep size. Default is .9.

OFF Alpha label that causes the simulator to ignore IMPES stability restrictions.

ON Alpha label that causes the simulator to take IMPES stability restrictions into account using the most recent values of ststar, stslim, and mxstsc.

stslim Largest fraction of the maximum stable IMPES timestep at which the simulator is permitted to run. Default is 1.0.

NOCUTS Alpha label that causes the simulator to ignore violations of the stslim limit.

mxstsc Maximum number of timestep reductions due to violation of the stslim limit on a single timestep. Default is 3.

FLOWIN Alpha label indicating that flow both into and out of blocks is to be checked for stability. Default is to only check the flow out of blocks.

5000.4.4 7-439


NOTE: 1. Unless OFF is specified, for each timestep the timestep size will be set equal to ststar times the maximum stable IMPES timestep, provided that this timestep would satisfy the constraints imposed by the DT card.

2. Unless OFF or NOCUTS is specified, the simulator will enforce the stslim limit. If the chosen timestep exceeds stslim times the maximum stable IMPES timestep, it is immediately reduced to the target value. This reduction is not counted as a timestep cut.

3. After mxstsc-1 timestep reductions on a single timestep, the timestep size is set equal to dtmin (see DT card).

4. If more than mxstsc reductions are required on a single timestep due to the stslim limit, the run is terminated and a restart record is written at the end of the last successful timestep.

5. The maximum stable IMPES timestep is constrained by the total volumetric throughput (based on a Buckley-Leverett-type analysis) and by the possible composition changes for each phase in each gridblock. Complete details are available in a separate document. Inactive blocks are ignored.

6. The parameters are order-dependent and must be specified if subsequent parameters are input.

7.1.6 Maximum Variable Change Overshoot (MAXOVR)

00 The MAXOVR card is used to control when a timestep cut occurs due to maximum variable changes over a timestep. If any variable changes relative to its maximum allowed (from the DT card) more than the factor specified on this card, a timestep cut will occur. Does not aply to VIP-THERM.

MAXOVR maxovr

00 Definition:

maxovr Maximum variable change factor above which a timestep cut will occur. Default is 1.5.

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7.1.7 Convergence Tolerance on Unknowns (TOLD)

TOLD tolp (tolt) tols tolv tolz

00 Definitions:

tolp Convergence tolerance used to test the pressure changes occurring in each gridblock during each Newton (outer) iteration, psia (kPa). Default is 0.1 psia.

tolt Convergence tolerance used to test the changes in temperature occurring in each gridblock during each outer iteration, °F(°C). Default is 100°F. Enter only in VIP-THERM.

tols Convergence tolerance used to test the changes in water saturation occurring in each gridblock during each outer iteration. Default is 0.0001.

tolv Convergence tolerance used to test the changes in vapor fraction (IMPES) or gas saturation (implicit) occurring in each gridblock during each outer iteration. Default is 0.0001.

tolz Convergence tolerance used to test the changes in total composition (IMPES) or primary phase composition (implicit) occurring in each gridblock during each outer iteration. Default is 0.0001.

NOTE: 1. Convergence is achieved when none of the pressure, saturation, vapor fraction (gas saturation), or composition changes occurring over the previous iteration are larger in absolute value than the corresponding tolerances.

2. The TOLD tests are independent of the TOLR tests. If either set of convergence tests is satisfied no further outer iterations are performed and the timestep is concluded.

3. A negative value for a tolerance causes that variable to be ignored in the convergence check.

4. A zero value for any of the tolerances forces non-convergence based on maximum changes.

5000.4.4 7-441


7.1.8 Convergence Tolerance on Residuals (TOLR)

00 The TOLR card is used to define a set of convergence tolerances based on how well the conservation equations are resolved. Separate tolerances are specified for the water material balance equation and for the sum of the hydrocarbon material balance equations, and they can be in terms of relative reduction or absolute values. For the relative reductions, the values are relative to the largest residuals encountered during the first itnmax/2 outer iterations, which is normally the residuals at the start of the first iteration. If relative reductions are being used and the maximum residual is less than 1E-4, the relative reduction for that constituent will not be required.

TOLR tolrw tolhc (tole)

ABSTOL RELTOL

ABSRES RELRES

(SUM) (MAX)

00 Definitions:

tolrw Convergence tolerance used to test the water "residual". This tolerance measures how well the water material balance equation for each gridblock has been solved. Default is 0.001.

tolhc Convergence tolerance used to test the hydrocarbon "residual". This tolerance measures how well the hydrocarbon material balance equations for each gridblock have been solved. Default is 0.001.

tole Convergence tolerance used to test the energy balance “residual.” This tolerance measures how well the energy balance equations for each gridblock have been solved. Default is 0.001. Enter only in VIP-THERM.

ABSTOL Alpha label indicating that the water and hydrocarbon residuals are to be checked directly against tolrw and tolhc, respectively. This is the default in VIP-COMP or VIP-ENCORE if the TOLR card is input but neither ABSTOL nor RELTOL are specified.

RELTOL Alpha label indicating that the water and hydrocarbon residuals must be decreased from the values at the beginning of the timestep by at least the factors tolrw and tolhc, respectively. This is the default in VIP-THERM, and this is the default in VIP-COMP or VIP-ENCORE if no TOLR card is input.

ABSRES Alpha label indicating that the residuals to be checked are calculated simply as the maximum residuals over all gridblocks. This is the default.

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RELRES Alpha label indicating that the residuals to be checked are calculated as the maximum over all gridblocks of the water residual divided by the water volume (tolrw), the hydrocarbon residual divided by the number of hydrocarbon moles (tolhc), and, in VIP-THERM, the energy residual divided by the total energy (tole).

SUM Alpha label indicating that convergence is to be achieved if the sum over all gridblocks of the water, hydrocarbon, and energy residuals (absolute) are reduced below the tolerances as defined by the ABSTOL/RELTOL settings. This is the default in VIP-THERM.

MAX Alpha label, valid only in VIP-THERM, indicating that only the maximum residuals over all gridblocks are to be checked, as is the default in VIP-COMP and VIP-ENCORE.

NOTE: 1. When the residual error in each material balance equation in each gridblock (or over all gridblocks, for the SUM option) satisfies the appropriate tolerance, the equations are assumed to have been solved and the timestep is concluded.

2. The TOLR tests are independent of the TOLD tests. If either set of convergence tests is satisfied, no further outer iterations are performed and the timestep is concluded.

3. For the combination of ABSTOL and ABSRES, the units of tolrw and tolhc are STB/D (STM3/D) and lb-moles/D (lb-moles/D), respectively. In VIP-THERM, the unit of tole is Btu/D (kj/D).

4. For fluid tracking cases, the recommended tolerance type is ABSTOL RELRES.

7.1.9 Saturation Convergence Tolerance for OPTMBL and VOLBAL (TOLSCN)

TOLSCN errsat

00 Definition:

errsat Convergence tolerance used to test the saturation constraint equation. Default is 0.005.

NOTE: When using the OPTMBL option or the VOLBAL option, errsat is used to test for convergence of the saturation constraint equation.

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7.1.10 Well Convergence Tolerance for OPTMBL and VOLBAL (TOLWCN)

TOLWCN errwel

00 Definition:

errwel Convergence tolerance used to test the well constraint equation. Default is 0.00001 for OPTMBL and 0.01 for VOLBAL.

NOTE: When using the OPTMBL option or the VOLBAL option, errwel is used to test for convergence of the well constraint equation.

7.1.11 Maximum Allowable Material Balance Error (ABORT)

00 The ABORT card defines the maximum allowable material balance error. When this is reached, the program automatically terminates. This automatic termination control is activated only by data entry.

ABORT ew ehc ee

00 Definitions:

ew Maximum allowed water material balance error before the program terminates.

ehc Maximum allowed hydrocarbon material balance error before the program terminates.

ee Maximum allowed energy balance error before the program terminates. Enter only in VIP-THERM.

NOTE: 1. Both values ew and ehc must be included on the card in the above order. A zero entry is ignored. An ee value is also required for VIP-THERM.

2. The program compares the normalized cumulative balance error to these constraints at the end of each timestep.

00 Example:

00 ABORT 0.001 0.001

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7.1.12 Minimum BHP Damping Factor (CBHPMN)

00 The CBHPMN card is used to set the minimum BHP damping factor. A value of

1.0 will cause the CHKBHP subroutine to be ignored. Allowed values are 0

cbhpmn 1.0.

CBHPMN cbhpmn

00 Definitions

cbhpmn Minimum BHP damping factor. Default is 0.05.

7.1.13 Table Extrapolation Control (CHKTAB)

CHKTAB

PVT

BHP

ALL

NONE

(nex)

00 Definitions:

PVT Alpha label that allows the simulator to extrapolate the PVT/K-value table during look-ups.

BHP Alpha label that allows the simulator to extrapolate the production and injection BHP tables during look-ups.

ALL Alpha label that allows the simulator to extrapolate both the PVT/K-value and BHP tables during look-ups. This is the default.

NONE Alpha label that causes the simulator to stop rather than extrapolate outside the table boundaries.

nex Number of table extrapolations allowed before run is terminated. Default is 0.

00 The CHKTAB card is used to control the action taken when table look-ups require extrapolation outside the range of the defined data. This is generally not encouraged and can lead to convergence problems. By default, extrapolation warning messages are printed in the output file, along with the offending values. If the NONE option is specified then the model will write a restart record at the end of the last acceptable timestep and the run will be terminated. The PVT, BHP and ALL options will write warning messages until nex extrapolations have been

5000.4.4 7-445


performed, then the run will be terminated (as above). A value of zero for nex will suppress run termination. Tables checked for extrapolation include the black-oil PVT/K-value tables (end of timestep only) and the wellbore hydraulics (BHPTAB tables and BHITAB tables (every occurrence)).

7.1.14 Timestep Size Factors (MXDTCF, MXDTFC, DTCUTF)

MXDTCF mxdtcf

MXDTFC mxdtfc

DTCUTF dtcutf

00 Definitions:

mxdtcf Maximum timestep size increase factor after a successful timestep. Default is 5.0.

mxdtfc Maximum timestep size increase factor after timestep had to be cut due to a convergence failure. Default is 1.25.

dtcutf Timestep size cutback factor following a convergence failure. Default is 0.5.

7-446 5000.4.4


7.2 Matrix Solution Options

00 For each outer iteration, VIP-EXECUTIVE must solve one or more large linear systems of equations. This step is usually the most expensive activity performed during an outer iteration. The choice of matrix solver can have a very large impact on the overall cost of the simulation. VIP-EXECUTIVE offers both direct and iterative matrix solvers for this task.

00 Direct Solver

GAUSS Gaussian elimination with the D4 ordering of unknowns.

00 Iterative Solvers

BLITZ Preconditioned Generalized Minimum Residual Method (Reference 5).

EXCEL Generalized Incomplete Factorization Preconditioning.

00 A matrix solver should probably be specified at the beginning of every simulation run, but it may be defaulted. At time = 0, the default is BLITZ for single grid runs and CBLITZ (see Section 13.5 for these parameters) for multigrid runs. At time > 0 the matrix solver choice and parameters are retrieved from the restart file.

00 EXCEL and BLITZ are available for both the IMPES and fully implicit formulation options. With certain restrictions, BLITZ and EXCEL can be invoked for reservoir models that use either the FAULT option or the PINCHOUT option. Each of these options generates nonstandard connections between gridblocks.

00 A connection is standard when a gridblock, identified by the coordinates (i, j, k), connects to an adjoining gridblock with coordinates of one of the forms:

00 (i-1, j, k)(i+1, j, k)(i, j-1, k)(i, j+1, k)(i, j, k-1)(i, j, k+1)

00 A nonstandard connection is called logically vertical when the connection exists between gridblock (i, j, k) and one of the gridblocks:

00 (i-1, j, *)(i+1, j, *)(i, j-1, *)(i, j+1, *)

00 where * denotes any value less than or equal to NZ other than k. A nonstandard

5000.4.4 7-447


connection to any other gridblock is called logically nonvertical.

7.2.1 Gaussian Elimination (GAUSS)

00 Invokes Gaussian elimination.

GAUSS

NOTE: 1. Use of Gaussian elimination maximizes the probability of successful convergence, but it also tends to increase computer time and storage requirements.

2. This option does not allow for faults.

7.2.2 Iterative Solver (EXCEL)

00 EXCEL is an iterative solver, available for both the IMPES and fully implicit options. It will handle all types of nonstandard connections, including logically nonvertical ones. For an explanation of this method, see Reference 4.

EXCEL

ITER NOITER

(ilu) (north) (rtol) (nit)

00 Definitions:

ITER Alpha label indicating that an EXCEL iteration summary should be printed.

NOITER Alpha label indicating that an EXCEL iteration summary should not be printed. This is the default.

ilu Incomplete factorization level in EXCEL. Default is 0.

north Number of orthogonalizations used in EXCEL. Minimum value is 4, maximum value is 20. Default is 10.

rtol Tolerance for convergence of EXCEL. Default is 0.001.

nit Maximum number of iterations allowed in EXCEL. Minimum value is 5. Default is 25.

NOTE: The ITER/NOITER label is optional and may be omitted. The other parameters are order-dependent and must be specified if subsequent parameters are input.

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7.2.3 Iterative Solver (BLITZ)

00 BLITZ is an iterative solver, available for both the fully implicit and IMPES options. For an explanation of this method, see Reference 5.

BLITZ param1 . . . paramn (card 1)value1 . . . valuen (card 2)

00 Definitions:

ITER A BLITZ iteration summary should be printed. No entry should be made on card 2 corresponding to this entry.

NOITER A BLITZ iteration summary should not be printed. This is the default. No entry should be made on card 2 corresponding to this entry.

NORTH Maximum number of orthogonalizations for the generalized conjugate residual method in BLITZ. Default is 10.

RTOL Norm (EUCLIDEAN) residual reduction ratio convergence criterion in BLITZ. Default is .005.

NIT Maximum number of iterations allowed in BLITZ. Default is 20.

JLUN Preconditioning option in BLITZ for multi-variable equations (IMPLICIT):

0 = Reduced system/diagonal scaling.1 = Reduced system/ILU(0).2 = Line Gauss-Seidel.3 = Modified Nested Factorization, Option 1.4 = Diagonal scaling.5 = MVP default, Option 1.6 = MVP, Option 2Default is 1 without faults and 2 with faults.

JLU1 Preconditioning option in BLITZ for single-variable equations (IMPES or CPR):

-1 = D4 Gauss (direct solution).0 = Reduced system/diagonal scaling.1 = Reduced system/ILU(0).2 = Line Gauss-Seidel.3 = Modified Nested Factorization, Option 1.4 = Modified Nested Factorization, Option 2.5 = Modified Nested Factorization, Option 3.

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6 = MVP, Options .7 = MVP, Option 2.

If the reservoir model does not have faults, default is 1 for IMPES and 3-D constrained pressure residual problems and is -1 for 2-D constrained pressure residual problems. With faults, the default is 3.

PTOL Residual norm reduction ratio convergence criterion for pressure solution (for implicit formulation with jcor=1). Default is .005.

JCOR Constraint option associated with the pressure solution (available with implicit formulation only if jcpr=1; always available with IMPES formulation):

0 = no constraints.1 = use line constraints.Default is 1.

JCPR Constrained pressure residual method option (implicit formulation only):

0 = no pressure predictor step.1 = use pressure predictor step.Default is 1.

JOPTN Ordering option for line constraints for multi-variable equations (IMPLICIT):

0 = Automatic determination.

3-D Problems:1 = XYZ 3 = XZY 5 = YZX2 = YXZ 4 = ZXY 6 = ZYX

2-D Problems:1 = XY or XZ 2 = YX or ZX

Default is 0 for unfaulted problems. With faults, default is 2 for 2-D problems, 6 for 3-D problems with NY < NX, and 4 otherwise.

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JOPT1 Ordering option for line constraints for single-variable equations (IMPES or CPR):

0 = Automatic



Defaults are the same as joptn.

JGAUS Solution method for line constraints when jcor=1:

0 = Iterative solution1 = Direct solutionDefault is 0 for 3-D problems. Must be 1 for 2-D problems.

ADJTOL Turns on the adjustable linear tolerance algorithm with default values for TOLMN, TOLMX, TOLST and TOLEX. No entry should be made on card 2 corresponding to this entry.

TOLMN Turns on the adjustable linear tolerance algorithm and specifies the minimum value of linear tolerance to be used throughout the simulation. Default is RTOL so that, if RTOL is defaulted, then TOLMN defaults to 5.E-03 but, if RTOL is specified, then TOLMN is set to the specified RTOL value. TOLMN must range between 0.0 and 1.0.

TOLMX Turns on the adjustable linear tolerance algorithm and specifies the maximum value of linear tolerance to be used throughout the simulation. Default is 0.5. TOLMX must range between 0.0 and 1.0.

TOLST Turns on the adjustable linear tolerance algorithm and specifies the value of linear tolerance to be used in the first Newton step of each timestep. Default is max(TOLMX, 5 * RTOL). TOLST must be less than TOLMX and greater than or equal to 0.0.

TOLEX Turns on the adjustable linear tolerance algorithm and specifies the value of the exponent in the power law used to control the reduction of the linear solver tolerance as the Newton iteration nears convergence. Default is 3.0. TOLEX must be nonnegative.

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NOTE: A less storage intensive algorithm may be requested by specifying a negative value for NORTH. For example, to specify six orthogonalizations with this algorithm, use NORTH=-6. This algorithm will cause an increased amount of execution time, approximately equal to an extra iteration.

00 Examples

00 BLITZ ITER

00 BLITZ ITER NIT TOLST JLUN15 0.3 3

00 BLITZ ADJTOL PTOL RTOL

00 1.E-5 1.E-4

7.2.4 Bad Solution Indicator (SLVCUT)

00 The SLVCUT card is used to activate the option to have the solver return a bad solution indicator when convergence seems to be failing or very slow. In this case, a convergence failure is assumed and the timestep will be repeated, potentially saving a large number of iterations.

SLVCUT ON

OFF (itn)

00 Definitions:

ON Alpha label indicating that the timestep will be repeated when the solver returns a bad solution indicator after Newton iteration itn. This is the default if the card is entered without specifying ON or OFF.

OFF Alpha label indicating that the option is off. This is the default if the SLVCUT card is not entered.

itn Newton iteration after which the bad solution indicator would be returned. Default is 1.

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7.3 Implicit Well Options

7.3.1 Implicit Well Calculations in IMPES Grids (IMPWEL)

00 The IMPWEL card is used to specify the level of implicitness in the well rate equations to be used for wells within IMPES grids. The default is OFF, which uses the standard IMPES formulation for the wells, with the rates implicit in pressure, only. If the feature is set to ON, the well rate equations will be implicit in saturations, also. This requires additional work in reducing the possible well constraint equations, but in most cases, it will result in larger, stable timestep sizes for runs involving IMPES grids.

IMPWEL ON

OFF

00 Definitions:

ON Alpha label indicating that well constraint equations are to be set up and that these equations are to be implicit in both pressure and relative permeabilities.

OFF Alpha label indicating that well constraint equations are to be set up and that these equations are to be implicit in pressure only. This is the default.

NOTE: 1. The implicit well option may not be used with the following options:

Ž VE

Ž CO2 in water

2. If IMPWEL is used in conjunction with OPTMBL and if any FRES or FSTD reinjection wells are active, it is recommended to also set ITNSTQ to 1 iteration, in order to reduce the number of outer iterations that might result when the production rates are updated. The well convergence tolerance, TOLWCN, applies to both production and injection wells

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7.4 Automatic Parameter Settings (FASTSIM)

00 The FASTSIM card is used to activate a number of parameter settings, regardless of what has been introduced before it. For additional tuning, the user can then reintroduce parameter settings, following the FASTSIM data line, to override the defaulted settings.

00 The data lines listed below are actually entered into the edited data stream, so they will appear on the echo print of the data. However, the data listed are the FIELD units equivalents. If the run is being made in METRIC or LAB units, the necessary conversions are made accordingly, and the echo print will reflect the proper specified operating units.

00 FASTSIM is coded such that it will work regardless of formulation (IMPES, IMPLICIT, or mixed).

FASTSIM

00 The following data lines are inserted into the data deck:

00 DT -1.0 1.0 183.0 1000.0 0.05 0.05 0.05 BOTH BOTH NONE BOTHDTMPL 1000.0 0.20 0.20 0.20 BOTH BOTH NONE BOTHITNLIM 1 10 1500.0 0.25 0.50 0.25ITNMPL 1500.0 0.50 0.99 0.50MAXOVR 2.0TOLR 0.001 0.001 RELTOL SUMTOLD 1.0 0.01 0.01 0.01TOLWCN 0.001TOLSCN 0.005ITNSTP 3ITNSTQ 3ITNGRE 3ITNTHP 3IMPTHP ONIMPSTAB 1.1 1.3DTQMAX 5.0

00 In addition, the solver defaults, depending on the grid system, as well as a number of solver parameters (some are BLITZ (Section 7.2.3), some CBLITZ (Section 13.5), some both):

00 NIT = 50NORTH = 49JLUN = 4JLU1 = 3JCOR = 1JOPT1 = 6

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JOPTN = 6NBEPS = 0JCPR = 1RTOL = 0.001PTOL = 0.001Solver iteration summary turned off

00 For multigrid problems, additional settings are made:

00 NOPTG = 6NITG = 1, but for radial grids NITG = 3RTOLG = 0.001JCPR = 0

00 For a parallel run:

00 NBEPS = 3

00 Also, for a LAB units run, the following changes are made:

00 dt = 0.001 hoursdtmin = 0.001 hoursdtmax = 1.0 hourdtqmax = 0.01 hours

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7.5 Interactive Suspend Option

00 The INTERACTIVE card allows the user to suspend execution at the beginning of the current timestep. Execution will resume when the program detects the existence of a file named vip_interactive_resume in the directory in which the program is running. The content of the file does not matter, only its existence.

00 Optionally, through the FILE keyword on the INTERACTIVE card, a file may be specified that contains recurrent data to be read immediately upon resumption of execution. If any errors are detected in the data in this file, or if the file does not exist at the time execution is resumed, execution will go back into suspend mode.

00 The default is for suspension to occur at the beginning of every timestep once the option has been turned on. The BATCH keyword on the INTERACTIVE card instructs the program to only suspend at the beginning of this timestep. Normal execution will resume after this one suspension.

00 The BATCH card causes the interactive suspend option to be immediately turned off. This card would be input in the file designated by FILE on the INTERACTIVE card or possibly in the original dataset at a future TIME or DATE card.

00 Two files are created in the running directory by this option. The file named vip_interactive_status is created at the time of the suspension. It contains the current time-of-day and current date. It will also indicate if any errors were found in the specified data file. These errors are written to a file named vip_interactive_errors.

00 Note that the entire block of data that contains the INTERACTIVE card is read before execution is suspended. The only data that will be read when execution is resumed is the data contained in the file designated by FILE on the INTERACTIVE card.

00 It is important to remember that the three files vip_interactive_status, vip_interactive_resume, and vip_interactive_errors exist only in the directory in which the program is running. They will not be in the working directory from which a remote-execution job was submitted.

00 A potential problem exists regarding TIME cards when execution resumes. The program searches for what it assumes is the unique TIME or DATE card following the INTERACTIVE card. In general this is no problem unless the TIME PLUS option is used on the card following INTERACTIVE. An exact replica of this card could have existed in the deck before the INTERACTIVE, causing the resumed execution to start in the wrong part of the dataset. To avoid the problem make sure all TIME PLUS cards are unique; extra spaces will do.

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7.5.1 Interactive Card (INTERACTIVE)

INTERACTIVE (BATCH) (SLEEP slpsec) (FILE filenm)

00 Definitions:

INTERACTIVE Alpha label indicating that the interactive suspend option is on.

BATCH Alpha label indicating that the execution should suspend only at the beginning of this timestep. Normal execution resumes after this one suspension. The default is to suspend execution at the beginning of each timestep.

SLEEP Alpha label indicating that the number of sleep seconds is being entered.

slpsec The number of seconds between checks for the existence of the resume file. Default is 5 seconds.

FILE Alpha label indicating that a file containing recurrent data is being specified that should be read when execution is resumed.

filenm The pathname to the file from which data should be read.

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7.5.2 BATCH Card (BATCH)

BATCH

00 Definition:

BATCH Alpha label indicating that the interactive suspend option is to be immediately turned off.

00 Examples

00 Run starts at 1/1/2000. Suspend execution after each of first 2 years. Enter new data each time.

00

START

DATE 1 1 2001INTERACTIVE BATCH FILE /home/user/data

DATE 1 6 2001

00 DATE 1 1 2002INTERACTIVE BATCH FILE /home/user/data

00

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7.6 Interactive Recurrent Data Changes

00 Changes to the recurrent data can be made while the simulation is in progress.

1. The user needs the process identification (pid) of the run so as to be able to send a signal to the process. The pid can be obtained by issuing the unix ‘ps’ command on the machine that is executing the simulation. The pid is also written to Fortran Unit 15 which is referred to as the timestep summary file elsewhere. The user can type the unix ‘head’ command on the timestep summary file and get the pid from the first line of the file.

2. The user then sends the unix hangup signal to the process by the following unix command.

kill -HUP pid

Once the simulator receives the hangup signal it will continue executing the current timestep, then searches the recurrent data file for the last DATE (TIME) line read, writes relevant information to the output and status output files (Fortran Units 6 and 25), and suspends itself.

3. On some systems, the output to the standard output file (Fortran Unit 6) may be buffered so the interrupt acknowledgement message may not appear in that output file (*.out) until after the job is continued. The simulation module can flush any buffers to the status output file (Fortran Unit 25, *.status). Recurrent data should NOT be modified until one of those files includes acknowledgement that it is safe to do so.

4. The user should then edit the output file, or use the unix ‘tail’ command to read the program messages and find which lines of the recurrent data file may be changed. In general any line following and including the last line read may be changed, while none of the preceding lines should be changed.

5. When the user is finished with the data changes, the simulation can be continued by sending the unix continue signal to the process.

kill -CONT pid

6. The user should check the output file to see if the data changes have been accepted and that the run is progressing.

NOTE: The hangup signal may be used repeatedly during a run. Recurrent data changes are not required to continue a run.

5000.4.4 7-459


7-460 5000.4.4

Chapter

8

00000Miscellaneous Options

8.1 Energy Minimization Phase Equilibrium (VIP-COMP)

8.1.1 Invoking the Gibbs Algorithm (GIBBS)

GIBBS (tcrit) (maxitr) (tskip) (tpbyp) (txbyp) (tfbyp) (itngbs)

00 Definitions:

tcrit Tolerance value in the test for the critical condition. Default is 0.15.

maxitr Maximum number of iterations allowed in the Gibbs energy minimization process. Default is 30.

tskip Tolerance value in the test to skip the phase equilibrium calculations for two-phase blocks. Default is 0.05.

tpbyp Tolerance value for block pressure change, psi (kPa). Default is 1 psi.

txbyp Tolerance value for composition change. Default is 0.01.

tfbyp Tolerance value for the stability function. Default is 0.015.

itngbs Maximum number of outer iterations that phase stability test is performed on for single-phase hydrocarbon gridblocks. Default is 5.

00 This card invokes the phase stability test and Gibbs energy minimization algorithm for phase equilibrium calculations. The GIBBS card automatically activates the feature which identifies gridblocks near the critical point and allows large changes of oil saturation, gas saturation, and vapor fraction in these blocks during simulation. All parameters on the card are optional, but they are order dependent and must be specified through the last value required. Parameters not specified will be set equal to their defaults. PHFLAG on the OUTPUT card will print the phase equilibrium condition in each gridblock for the IMPES formulation. Codes are as follows:

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0. Two phase block.

1. Single-phase block. The fluid is gas.

1.1 Single-phase block. The fluid is gas and is determined to be far from the two-phase region.

1.5 Single-phase block. The fluid is supercritical and is far from the critical point.

2. Single-phase block. The fluid is oil.

2.1 Single-phase block. The fluid is oil and is determined to be far from the two-phase region.

-3. Two-phase block. The fluid is near the critical point at the end of the timestep.

-3.5 Two-phase block. The fluid is near the critical point at the beginning of the timestep.

-1. Single-phase block. The fluid is supercritical. The fluid is near the critical point at the end of the timestep.

-1.25 Single-phase block. The fluid is supercritical. The fluid is near the critical point at the beginning of the timestep.

-1.5 Single-phase block. The fluid is gas and is near the critical point.

-2.5 Single-phase block. The fluid is oil and is near the critical point.

-1.75 Single-phase block. The fluid is gas. The fluid has changed phase during the timestep.

-2.75 Single-phase block. The fluid is oil. The fluid has changed phase during the timestep.

00 For a simulation run starting at time = 0 and the GIBBS card was input in VIP-CORE, the GIBBS option will automatically be on unless a GIBOFF card is specified in the initial set of recurrent data. The default values noted above will be used if no GIBBS card is input.

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8.1.2 Turning Off the Gibbs Algorithm (GIBOFF)

GIBOFF

00 The GIBOFF card is used to turn off the Gibbs energy minimization algorithm from this timestep onward. The Gibbs algorithm may only be reinvoked by respecifying the GIBBS card.

8.2 Successive Substitution Flash Data (VIP-COMP)

8.2.1 Definition of Flash Calculation Method (FLASH)

00 The FLASH card allows the user to define the flash calculation method and maximum allowable iterations for reservoir and surface flashes. The two available methods are accelerated successive substitution and Newton-Raphson with successive substitution preconditioning. The default method for reservoir flashes is accelerated successive substitution. The default method for surface flashes is Newton-Raphson.

FLASH maxss maxnrRES

SURF(ACC)

00 Definitions:

maxss Maximum number of successive substitution iterations allowed for a flash calculation. Default is 5 for flashes to surface conditions and 20 for flashes to reservoir conditions.

maxnr Maximum number of Newton-Raphson iterations allowed for a flash calculation. Default is 10 for flashes to surface conditions and 0 for flashes to reservoir conditions.

RES Alpha label indicating that the data on this card applies to flashes to reservoir conditions.

SURF Alpha label indicating that the data on this card applies to flashes to surface conditions.

ACC Alpha label indicating that accelerated successive substitution flash calculations will be performed.

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NOTE: 1. One and only one of the RES or SURF labels must be specified. There is no default. Separate FLASH cards can be input for RES and SURF.

2. If a FLASH card with the RES option is not input, then ACC (accelerated successive substitution) is the default. If a FLASH card with the SURF option is not input, accelerated successive substitution calculations are not performed. When a FLASH card is input, ACC must be specified to invoke the option.

8.2.2 Control of Flash Calculations (KMAX)

00 VIP-EXECUTIVE allows the input of data which controls the use of the accelerated successive substitution flash calculation. By default, phase behavior calculations are imbedded in the Newton-Raphson mass balance calculations. Only when a block becomes two-phase, and a flash calculation is to be performed, is the accelerated successive substitution preconditioning used. However, for difficult fluids near their critical point, it may be advantageous to provide a more robust flash treatment. The data cards described below should be entered only for fluids that have shown some difficulty in phase behavior convergence. The use of this data may significantly affect computation time.

KMAX KMAX2 KAC KAC2

PSAT

NOPSAT (SS) (EST) (card 1)

kmax kmax2 kac kac2 (card 2)

00 Definitions:

KMAX Alpha label for maximum iterations during preconditioning for gridblocks becoming two-phase.

KMAX2 Alpha label for maximum iterations during preconditioning for mass balance calculations.

KAC Alpha label for maximum acceleration steps to be performed during preconditioning for gridblocks becoming two-phase.

KAC2 Alpha label for maximum acceleration steps to be performed during preconditioning for mass balance calculations.

PSAT Alpha label indicating that the saturation pressure calculation will be performed for all single phase blocks. This is the default.

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NOPSAT Alpha label indicating that the saturation pressure calculation will be bypassed for blocks that have previously failed the saturation pressure calculation.

SS Alpha label indicating that phase equilibrium calculations in the mass balance calculation should be bypassed. This option should be used only for near-critical fluids that have not converged without this option.

EST Alpha label indicating that the flash calculation should use estimates of initial K-values from a correlation instead of from current phase compositions at the beginning of phase behavior calculations. This option should be used only for near-critical fluids which have difficulty converging.

kmax Maximum number of iterations during preconditioning for gridblocks becoming two-phase. If X is entered for this field, the default value is 50. If this card is not entered, the default value is 15.

kmax2 Maximum number of iterations during preconditioning for mass balance calculations. If X is entered for this field, the default value is 50. If this card is not entered, the default value is 0.

kac Maximum number of acceleration steps during preconditioning for gridblocks becoming two-phase. If X is entered for this field, the default value is 10. If this card is not entered, the default value is 2.

kac2 Maximum number of acceleration steps during preconditioning for mass balance calculations. If X is entered for this field, the default value is 10. If this card is not entered, the default value is 1.

00 Examples:

00 (1) KMAX KMAX2 KAC KAC2X X X X

00 is equivalent to

00 KMAX KMAX2 KAC KAC250 50 10 10

00 (2) Omitting the data cards from input is equivalent to:

00 KMAX KMAX2 KAC KAC215 0 2 1

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NOTE: Any occurrence of this data supersedes previous occurrences of this data.

8.3 Gas Percolation Algorithm (GASPERC) (Not available in VIP-THERM)

GASPERC OFF

ON

00 Definitions:

OFF Alpha label that causes the gas percolation algorithm to not be used. This is the default if the card is not input.

ON Alpha label that causes the gas percolation algorithm to be used.

8.4 Gas Remobilization Option (GASRMON) (Not available in VIP-THERM)

00 The gas remobilization option models the remobilization of trapped gas resulting from gas expansion during pressure blowdown. The option may be turned on any time during the simulation. To invoke this option, gas remobilization tables must be input in the initialization module input data set (see Section 4.3.9, Gas Remobilization Option, of the VIP-CORE Reference Manual).

GASRMON grmdsw

00 Definitions:

GASRMON Alpha label indicating that the gas remobilization option is invoked at the time specified in the preceding TIME/DATE card. This option may only be invoked once in a simulation run and may not be turned off after it is invoked.

grmdsw Incremental water saturation increase (from the gridblock historic minimum water saturation) as a fraction of total pore volume beyond which a gridblock may be considered as a gas expansion gridblock and hence is subject to remobilization calculation. The default value for grmdsw is 0.02.

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NOTE: A gridblock is subject to remobilization calculation only if all of the following conditions are met at the time this option is invoked.

1. The water saturation must be greater than the historical minimum water saturation (Swmin) plus the user-controlled incremental saturation (grmdsw), i.e., Sw > Swmin + grmdsw.

2. The gas saturation must be less than or equal to the trapped gas saturation (Sgtr,m) corresponding to the gridblock historical maximum gas saturation (Sgmax,m), i.e., Sg Sgtr,m(Sgmax,m).

3. The gridblock historical maximum gas saturation must be greater than its critical gas saturation, i.e., Sgmax,m > Sgc,m.

00 Example:

00 TIME 3650.CC Turn on Gas Remobilization OptionCGASRMON 0.05

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8.5 Modified Land’s Constant for Hysteresis (MODLAND)

00 The MODLAND card is used to specify the form of Land’s constant to use for both gas phase and oil phase hysteresis in calculating the trapped saturations.

MODLAND ON

OFF

00 Definitions:

ON Alpha label indicating that the modified Land’s constant is to be used. This is the default if neither ON nor OFF is specified.

C 1Snwr Snwc–--------------------------- 1

Snwi Snwc–---------------------------–=

OFF Alpha label indicating that the original Land’s constant is to be used:

C 1Snwr---------- 1

Snwi----------–=

This is the default if the MODLAND card is not specified.

NOTE: Snwr= residual non-wetting phase saturation.Snwi= maximum historical non-wetting phase

saturation.Snwc= critical non-wetting phase saturation.

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8.6 Modifying VIP-CORE Array Data

00 OVER and VOVER cards may be used to modify certain gridblock arrays that are read or computed in VIP-CORE. The OVER card is used to apply a constant arithmetic operation to a portion of the grid system. The VOVER card modifies the specified array data with an individual value for each changed gridblock.

8.6.1 Override Modification (OVER)

00 The OVER card is used to apply a constant arithmetic operation to a portion of the grid system. Only one title card is required, but the data cards may be repeated as necessary. The parentheses indicate optional values. They are not part of the data. Array names are shown in parentheses since any combination of the arrays can appear on the title card. Do not use parentheses during input. The array names can appear in any order. The order of #v’s on the data cards corresponds to the order of the array names. Although several array names can appear on the OVER card, it is generally less confusing to have "sets" of OVER cards, with each set modifying only one array.

00 OVER (NOCONVERT) array (array) (array) (array)(GRID name)

i1 i2NX

j1 j2NY

k1 k2NZ

#v (v2) (#v (v2)) (#v (v2)) (#v (v2))

(Repeat as necessary)

00 Definitions:

NOCONVERT Alpha label indicating that the values entered for these arrays are in internal units, ignoring whether the user has specified METRIC or LAB.

OVER Alpha label indicating that changes are to be made to the specified arrays:


ISATI Imbibition relative permeability/capillary pressure table pointers for hysteresis.

ITRAN Transmissibility region identifier.

TX(TR) X(R) direction transmissibilities.

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TY(TTHETA) Y(Theta) direction transmissibilities.

TZ Z direction transmissibilities.

TKWEXP Fractional flow exponent for extraneous tracked water types.

CR Rock compressibilities, psi-1 (kPa-1).

PV Effective pore volumes, rb (m3). The only operation allowed is = (equal).

PVDEF Pore volume multipliers due to deformation, fraction. This multiplier is applied after the effects of compressibility and compaction. Default is 1.

KX X- (or R-) direction permeabilities, md.

KY Y- (or Theta-) direction permeabilities, md.

KZ Z-direction permeabilities, md

GRID Data applies to a particular grid.

00 name Name of the grid. Default is ROOT.

00 Gridblock locations are defined by indices I, J, K in reference to the (x,y,z) or

(r,,z) grid. Modifications are applied to array elements lying in the portion of the grid defined by:

i1 i2j1 J j2k1 K k2 ,

where i1, j1, k1 are numeric, i2 is numeric or NX, j2 is numeric or NY, and k2 is numeric or NZ.

# An operator that describes how the array is to be modified. Any of the following symbols may be used:

+ add- subtract/ divide* multiply= equalGE values smaller than v will be set equal to v2LE values larger than v will be set equal to v2

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There are no spaces between the operator and the value, #v. except when # is GE or LE.

v The value to be applied to the indicated portion of the corresponding array by using the specified operation.

v2 The step value required for the GE and LE operators.

NOTE: Both PV and PVDEF may not be entered on OVER/VOVER cards within the same recurrent time block.The porosity deformation option (PORDEF in VIP-CORE) may not be active if any of the arrays CR, PV, PVDEF, KX, KY, KZ are entered.When one of the PV or PVDEF arrays is entered, an iterative method is used to recompute the pressures, compositions, saturations, etc., such that precise material balance is maintained.When any of the permeability arrays KX, KY, KZ are entered, the relative ratio of each gridblock permeability to its original permeability is computed. These factors are then applied to the appropriate standard, non-standard, and wellbore transmissibilities for all flows.

8.6.2 Override Modification, VIP-DUAL (OVER)

00 The following are additional arrays available when the DUAL option is invoked. Their use and effect is analogous to the normal use of the OVER card.


i1 i2NX

j1 j2NY

k1 k2NZ

#v (v2) (#v (v2)) (#v (v2)) (#v (v2))


00 Definition:


ISATF Fracture relative permeability/ capillary pressure table pointers.

ISATIF Fracture imbibition relative permeability/capillary pressure table pointers for hysteresis.

ITRANF Fracture transmissibility region identifier.

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TXF (TRF) X(R)-direction fracture transmissibilities.

TYF(TTHETF) Y(Theta)-direction fracture transmissibilities.

TZF Z-direction fracture transmissibilities.

TEX Exchange transmissibilities.

CRF Fracture rock compressibilities, psi-1 (kPa-1).

PVF Fracture effective pore volumes, rb (m3). The only operation allowed is = (equal).

PVDEFF Fracture pore volume multipliers due to deformation, fraction. This multiplier is applied after the effects of compressibility and compaction. Default is 1.

KXF X- (or R-) direction fracture permeabilities, md.

KYF Y- (or Theta-) direction fracture permeabilities, md.

KZF Z-direction fracture permeabilities, md

8.6.3 Individual Value Override Modification (VOVER)

00 The VOVER card modifies the specified array data with an individual value for each changed gridblock. A minimum of two cards must follow the VOVER card. The first contains the locations describing the gridblocks to be changed. The second card contains the altered values for those gridblocks. A new VOVER card and its corresponding data cards are read for each different portion of the grid system being altered.

00 VOVER (NOCONVERT) array(GRID name)

i1 i2NX

j1 j2NY

k1 k2NZ

(op)

values as necessary

00 Definitions:

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NOCONVERT Alpha label indicating that the values entered for this array are in internal units, ignoring whether the user has specified METRIC or LAB.

array One of the following array names to be alterered:


ISATI Imbibition relative permeability/capillary pressure table pointers for hysteresis.

ITRAN Transmissibility region identifier.

TX(TR) X(R) direction transmissibilities.

TY(TTHETA) Y(Theta) direction transmissibilities.

TZ Z direction transmissibilities.

TKWEXP Fractional flow exponent for extraneous tracked water types.

CR Rock compressibilities, psi-1 (kPa-1).

PV Effective pore volumes, rb (m3). The only operation allowed is EQ (equal).

PVDEF Pore volume multipliers due to deformation, fraction. This multiplier is applied after the effects of compressibility and compaction. Default is 1.

KX X- (or R-) direction permeabilities, md.

KY Y- (or Theta-) direction permeabilities, md.

KZ Z-direction permeabilities, md


00 name Name of the grid. Default is ROOT.

00 Gridblock locations are defined by indices I, J, K in reference to the (x,y,z) or

(r,,z) grid. Modifications are applied to array elements lying in the portion of

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the grid defined by:

i1 i2j1 J j2k1 K k2 ,

where i1, j1, k1 are numeric, i2 is numeric or NX, j2 is numeric or NY, and k2 is numeric or NZ.

op an optional keyword that defines the operation to apply to the array. Any of the following labels may be used:

ADD Add.SUB Subtract.DIV Divide.MULT Multiply.EQ Equal. This is the default.

00 Enough values must be read to replace all array elements in the designated portion of the grid. The number of values required is:

00 (k2 - k1 + 1) * (j2 - j1 + 1) * (i2 - i1 + 1) .

00 The order of replacement is by x-direction (r-direction) rows. All rows for the

first xy (r) plane are entered in order of increasing J index, followed by the remaining planes in order of increasing K index.

NOTE: Only one array can be changed with each VOVER card.Both PV and PVDEF may not be entered on OVER/VOVER cards within the same recurrent time block.The porosity deformation option (PORDEF in VIP-CORE) may not be active if any of the arrays CR, PV, PVDEF, KX, KY, KZ are entered.When one of the PV or PVDEF arrays is entered, an iterative method is used to recompute the pressures, compositions, saturations, etc., such that precise material balance is maintained.When any of the permeability arrays KX, KY, KZ are entered, the relative ratio of each gridblock permeability to its original permeability is computed. These factors are then applied to the appropriate standard, non-standard, and wellbore transmissibilities for all flows.

8.6.4 Individual Value Override Modification, VIP-DUAL (VOVER)

00 The following are additional arrays available when the DUAL option is invoked. Their use and effect is analogous to the normal use of the VOVER card.

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i1 i2NX

j1 j2NY

k1 k2NZ

(op)

values as necessary

00 Definitions:

array One of the following array names to be altered:

ISATF Fracture relative permeability/ capillary pressure table pointers.

ISATIF Fracture imbibition relative permeability/capillary pressure table pointers for hysteresis.

ITRANF Fracture transmissibility region identifier.

TXF(TRF) X(R) direction fracture transmissibilities.

TYF(TTHETF) Y(Theta) direction fracture transmissibilities.

TZF Z direction fracture transmissibilities.

TEX Exchange transmissibilities.

CRF Fracture rock compressibilities, psi-1 (kPa-1).

PVF Fracture effective pore volumes, rb (m3). The only operation allowed is EQ (equal).

PVDEFF Fracture pore volume multipliers due to deformation, fraction. This multiplier is applied after the effects of compressibility and compaction. Default is 1.

KXF X- (or R-) direction fracture permeabilities, md.

KYF Y- (or Theta-) direction fracture permeabilities, md.

KZF Z-direction fracture permeabilities, md

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8.6.5 Modifying Fault Connection Transmissibilities (FTRANS)

00 The FTRANS card may be used to modify the transmissibilities across arbitrary connections between gridblocks. No new fault connections may be established. The data must specify a VIP-CORE generated fault connection or a standard connection. If a standard connection is specified, the regular transmissibility array will be changed (this could also have been accomplished using OVER/VOVER).

FTRANS (GRID name1 (name2)) i1 j1 k1 i2 j2 k2 t tt (repeat as necessary)

00 Definitions:


name1 Name of grid1. Default is ROOT.

name2 Name of grid2. Default is name1.

i1 X(R) direction index for the block on the "left" of the fault.

j1 Y(Theta) direction index for the block on the "left" of the fault.

k1 Z direction index for the block on the "left" of the fault.

i2 X(R) direction index for the block on the "right" of the fault.

j2 Y(Theta) direction index for the block on the "right" of the fault.

k2 Z direction index for the block on the "right" of the fault.

t Transmissibility for the connection across the fault. This replaces any other transmissibility defined for the pair of blocks. Units for t are the same as those for transmissibilities read for the standard transmissibility arrays.

tt Thermal transmissibility for the connection across the fault. This replaces any other transmissibility defined for the pair of blocks. Units for tt are the same as those for thermal transmissibilities read for the standard arrays. Enter in VIP-THERM only (required).

8-476 5000.4.4


8.6.6 Modifying Fault Connection Transmissibilities, VIP-DUAL (FTRANF)

00 The FTRANF card may be used to modify the transmissibilities across arbitrary connections between fracture gridblocks. No new fault connections may be established. The data must specify a VIP-CORE generated fault connection or a standard connection. If a standard connection is specified, the regular transmissibility array will be changed (this could also have been accomplished using OVER/VOVER).

FTRANF (card 1)i1 j1 k1 i2 j2 k2 t (card 2)(repeat as necessary) (card 3)

00 Definitions:

i1 X(R) direction index for the fracture block on the "left" of the fault.

j1 Y(Theta) direction index for the fracture block on the "left" of the fault.

k1 Z direction index for the fracture block on the "left" of the fault.

i2 X(R) direction index for the fracture block on the "right" of the fault.

j2 Y(Theta) direction index for the fracture block on the "right" of the fault.

k2 Z direction index for the fracture block on the "right" of the fault.

t Transmissibility for the connection across the fault. This replaces any other transmissibility defined for the pair of fracture blocks. Units for t are the same as those for transmissibilities read for the standard fracture transmissibility arrays.

5000.4.4 8-477


8.7 Named Fault/Region Transmissibility Multiplier (MULTFL)

The MULTFL keyword is used to modify the transmissibilities between grid blocks that have been assigned a name. Grid blocks can be assigned a name using the FNAME parameter on the MULT (Section 1.6), FAULTS (Section 6.2), OVER (Section 7.2) and VOVER (Section 7.4) options in the VIP-CORE Reference Guide. Both standard and non-standard transmissibility connections if any are multiplied. 00

MULTFL fname tmul(Repeat as necessary)

Definition: 00

MULTFL Alpha character keyword.

fname Name or number identifying the fault or group of grid block to be operated upon.

tmul Transmissibility multiplier.

8.8 Inter/Intra Region Transmissibility Multiplier (MULTIR)

The MULTIR keyword is used to modify the transmissibilities between and within regions. The transmissibility regions are defined using the ITRAN(F) array data (Section 5.26 in VIP-CORE. In VIP-EXEC, the ITRAN(F) array can be modified using the OVER (Section 8.6.1) and VOVER options (Section 8.6.3). 00

MULTIRitr1 itr2 tmul (X) (Y) (Z)(Repeat as necessary)

Definition: 00

itr1, itr2 Positive integer values identifying transmissibility regions. The transmissibility regions are defined using the ITRAN(F) arrays (Section..). When itr1 and itr2 are different, the transmissibilities between these regions are multiplied by tmul wherever they are in contact. When itr1 and itr2 are equal the transmissibilities within the region are multiplied by tmul.

tmul Transmissibility multiplier between regions itr1 and itr2 wherever they are in contact.

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X Y Z Directions for applying the multiplier. The letters are order independent and spaces are optional. Default XYZ.

NOTE: The MULTIR option in VIP-EXEC always operates on both standard and non-standard connections.

8.9 Pressure Threshold for Limiting Grid Block to Grid Block Flow (PTHLD)

00 The PTHLD keyword is used to define threshold pressures for limiting flow between grid blocks that are part of an identifiable interface. Flow across any interface connection will not occur until the phase potential difference across the connection exceeds the threshold pressure. The phase potential difference to flow will be reduced by the threshold pressure.

00 Grid blocks can be assigned to an interface using the FNAME parameter on the MULT (Section 1.6), FAULTS (Section 6.2), OVER (Section 7.2) and VOVER (Section 7.4) options in VIP-CORE. Interfaces can also be defined between transmissibility regions. Transmissibility regions are defined using the ITRAN(F) array data (Section 5.25 and Section 5.26 in VIP-CORE. In VIP-EXEC, the ITRAN(F) array can be modified using the OVER (Section 8.6.2) and VOVER options (Section 8.6.3). The threshold pressure applies to both standard and non-standard connections. The threshold pressure arrays can be printed or mapped using PTHLD on the OUTPUT or MAPOUT keywords.

PTHLD fname PthresholdorPTHLD itr1 itr2 Ptreshold

EQUIL


00 Definition:

PTHLD Alpha character keyword.

fname Name or number identifying the fault or group of grid blocks that describe an interface.

itr1, itr2 Positive integer values identifying transmissibility regions. Transmissibility regions are defined using the ITRAN(F) arrays (). The threshold pressure will apply to all connections across the interface defined by itr1 and itr2. Itr1 and itr2 cannot be the same.

5000.4.4 8-479


Pthreshold Value of threshold pressure.

EQUIL This will calculate threshold pressures for each connection at the interface such that there will be no flow at initial conditions. The threshold pressures are set to the maximum phase potential difference for a particular connection.

This option is only allowed at time = 0.0.

NOTE: Pressure threshold values for a particular interface replace any previous values assigned to that interface.

00 Example:

00 PTHLD NW-SE 100PTHLD 1 2 200PTHLD 2 3 EQUIL

00 If any connection across the named interface NW-SE,are also shared across regions 1 and 2, or 2 and 3, then the pressure threshold values for these connections will be those from the latest specification.

8-480 5000.4.4


8.10 Phase Identification (PHASID)

00 When two hydrocarbon phases first appear in a gridblock, by default the simulator identifies the denser phase as the oil phase and the other phase as the gas phase. In some cases, especially when CO2 is injected, the evolving gas phase may actually be initially denser than the oil phase. After a short time, the gas phase would again become less dense than the oil phase. The symptom of this phenomenon is the appearance of a gas phase during the simulation that is denser than the oil phase. To prevent this from happening, the PHASID option provides an alternative means for identifying the oil or gas phases, based on composition. By default, the PHASID keyword (with no other parameters) will identify the phase with the greatest mole fraction of the heaviest component as the oil phase. Alternatively, the user can tag the oil or gas phase as the one that contains the greatest mole fraction of any one component.

PHASID OILGAS

cmpid

00 Definitions:

OIL Alpha label indicating that the oil phase will be identified as the phase that has the greatest mole fraction of component cmpid.

GAS Alpha label indicating that the gas phase will be identified as the phase that has the greatest mole fraction of component cmpid.

cmpid The alphanumeric component identifier. This identifier must have been previously identified on the COMPONENTS input card of VIP-CORE.

00 Examples:C Identify the oil phase as the phase that has the greatest moleC fraction of the heaviest component. PHASID

C Identify the gas phase as the phase that has the greatest moleC fraction of component CO2. PHASID GAS CO2

5000.4.4 8-481


8.11 Diffusion Activation/Deactivation (DIFFUSION)

The DIFFUSION card activates or deactivates the diffusion fluxes in VIP-EXEC. By default, diffusion is on when the DIFFUSION keyword is entered in VIP-CORE without the inclusion of the INITONLY keyword.

The DIFFUSION card must have been entered in VIP-CORE.

DIFFUSION OFFON

00 Definitions:

OFF Alpha label indicating that diffusivity calculations are to be turned off.

ON Alpha label indicating that diffusivity calculations are to be turned back on, or remain on. This is the default if neither OFF nor ON is entered.

00

8-482 5000.4.4

Chapter

9

00000Polymer Option (VIP-POLYMER)1

9.1 Polymer Physical Property Data

00 NOTE: Do not use the POLYMER option with the VOLBAL (Section 2.2.5) option.

00 The polymer physical property data for VIP-POLYMER can be introduced at any point within the recurrent data. However the data can only be read once.


00 If entered the DIM card(s) must immediately follow the RUN/STORAGE card, or be the first card(s) in the deck.

00 The POLYMER option allows additional changes to the default dimensions.


00 Definitions:

param Alpha labels of those dimension parameters being defined.

NCPDIM Number of polymer concentration points for each salinity curve in the reconstructed polymer properties tables. Default is 51.

NCPMAX Maximum number of different polymer property regions. Default is 1.

NESMAX Maximum number of salinity curves in each polymer properties table. Default is 1.

NSLUG Maximum number of steps in a polymer slug. Default is 4. See PSLUG card.

size The value or size of the corresponding parameter.

1. Available as a separately licensed option. Not available in VIP-THERM.

5000.4.4 9-483


9.1.2 Polymer Mode (POLYMER)

00 The POLYMER card must be followed by the polymer physical property cards. The POLYMER card puts the model in the polymer mode and will subsequently solve the polymer and electrolyte equations and include the polymer physical properties in the calculations.

POLYMER

9.1.3 Polymer Concentration/Salinity Table (POLYT)

00 The polymer concentration/salinity table defines the rock and fluid properties that depend on polymer concentration and salinity: polymer phase viscosity at zero shear rate, polymer adsorption, and the permeability reduction factor. These properties can be alternatively defined by functions as described in Section 9.1.4.

POLYT npt (NOPRTI) (PRTR) (card 1)ESALT PERM POR (card 2)csep perm por (card 3)CP VP0 CPADS RK (card 4)cp vp0 cpads rk (card 5)

00 Definitions:

POLYT Alpha label indicating that the data on the following cards are the polymer concentration/salinity table.

npt The table number. This value corresponds to the values of the IPOLYT array defined by either an OVER or VOVER card. (Section 9.6).

NOPRTI Alpha label indicating that the following table will not be printed on output. Default prints table.

PRTR Alpha label indicating that the reconstructed table will be printed on output. Default does not print the reconstructed table.

00 The values shown on Card 3 must appear in the order shown.

csep Effective salinity of the following table values, meq/ml.

perm Absolute permeability for the permeability reduction factor input on the following cards, md.

por Porosity for the permeability reduction factor input on the following cards, fraction.

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00 The values on Card 5 must appear in the order shown.

00 There must be a minimum of two Card 5 data cards.

cp Polymer concentration, ppm. Values must increase consecutively.

vp0 Polymer phase viscosity at zero shear rate, cp. Values must increase with increasing polymer concentration.

cpads Polymer adsorption, lb/ac-ft (g/m3) of bulk reservoir volume. Values must increase with increasing polymer concentration. Polymer adsorption is instantaneous and irreversible.

rk Permeability reduction factor, defined as the permeability to brine divided by the permeability to polymer solution. Values must increase with increasing polymer concentration. Permeability reduction is only applied to the aqueous phase and is considered irreversible.

NOTE: 1. Cards 2 through 5 can be repeated as necessary up to NESMAX times for each POLYT card. The values of csep within a particular table must increase consecutively, and a zero value is not allowed. The POLYT card can be repeated NCPMAX times. NESMAX and NCPMAX are defined by the DIM card (Section 9.1.1).

2. The use of the POLYT table option to define the polymer/salinity dependent properties disallows the use of the function option POLYF.

5000.4.4 9-485


9.1.4 Polymer Concentration/Salinity Functions (POLYF)

00 The polymer concentration/salinity functions define the rock and fluid properties that depend on polymer concentration and salinity: polymer phase viscosity at zero shear rate; polymer adsorption; and the permeability reduction factor. These

properties can be alternatively defined by tables as described in Section 9.1.3.

POLYF npf (card 1)AP1 AP2 AP3 SSLOPE (card 2)ap1 ap2 ap3 sslope (card 3)ADP1 ADP2 BP (card 4)adp1 adp2 bp (card 5)BRK CRK (card 6)brk crk (rkmax) (card 7)

00 Definitions:

POLYF Alpha label indicating that the data on the following cards are the polymer concentration/salinity functions parameters.

npf The functions number. This value corresponds to the values of the IPOLYT array defined by either an OVER or VOVER card Section 9.6).

00 Card 2 indicates that the data being read are polymer phase viscosity at zero shear rate parameters. The values on the data cards following this card appear in the order shown on this card. They must appear in the order shown.


ap1 Viscosity parameter (ppm-1) (meq/ml)1/sslope.



sslope Slope of log (viscosity) versus log (effective salinity) (dimensionless).

00 Card 4 indicates that the data being read are polymer adsorption parameters. The values on the data cards following this card appear in the order shown on this card.


adp1 Polymer adsorption parameter (lb/ac-ft)/(ppm), (g/m3)/(ppm).

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adp2 Polymer adsorption parameter (lb/ac-ft)/(ppm)/(meq/ml).

bp Polymer adsorption parameter (1/ppm).

00 Card 6 indicates that the data being read are permeability reduction factor parameters. The values on the data cards following this card appear in the order shown on this card.


brk Permeability reduction parameter (1/ppm).

crk Permeability reduction parameter. A positive value calculates RKMAX as a function of permeability, porosity, water saturation and salinity (darcy1/2) (ppm1/

3).

A negative value uses |crk| as the value of RKMAX, hence independent of permeability, porosity water saturation and salinity. (dimensionless).

rkmax The rkmax cutoff for calculated RKMAX, used when crk is positive, such that RKMAX rkmax (dimensionless). Default = 10.

NOTE: 1. Cards 1 through 7 can be repeated as necessary up to NCPMAX times. NCPMAX is defined by the DIM card (Section 9.1.1).

2. When the function option POLYF is chosen to define the polymer/salinity dependent properties, the table option POLYT is not allowed.

9.1.5 Non-Newtonian Viscosity Cards (SHEAR)

00 The effect of shear rate on the viscosity of the polymer phase is modeled by Meter’s (Reference 6) equation. The equivalent shear rate for multiphase flow in porous media is according to Hong’s (Reference 7) approximation. The required parameters are introduced by the following cards.

SHEAR nsh (GRID) (card 1)GAMMAC GAMHF POWN (card 2)gammac gamhf pown (card 3)

00 Definitions:

SHEAR Alpha label indicating that the data being read are shear rate viscosity parameters.

5000.4.4 9-487


nsh Polymer property region number corresponding to the values of the IPOLYT array defined by the OVER or VOVER cards. (Section 9.6)

GRID Alpha label indicating that the shear rate is a scalar property and calculated using the magnitude of the velocity vector at the gridblock center.


gammac Constant related to the power law exponent for non-Newtonian fluid viscosity. It is used to calculate the equivalent shear rate for fluid flow vs. porous media. Values of gammac range from 0.78 to 1.0.

gamhf Shear rate (1/sec) at which the polymer phase viscosity is equal to the average of the polymer solution viscosity at zero shear rate and of the water viscosity.

pown Exponent in Meter’s (Reference 6) viscosity equation.

NOTE: 1. If GRID is not specified, shear rate is calculated as a vector property. The directional property is calculated at the block faces.

2. When multiple polymer property regions are read, the method used for calculating shear rate is that specified on the last SHEAR card read.

3. Shear rate adjusted viscosities for well calculations require equivalent block radius and well radius data entered using the RFLOW or FPERF cards. Wells at the edge of the reservoir also require FLOANG data.

9-488 5000.4.4


9.1.6 Polymer Inaccessible Pore Volume Card (EPHIP)

00 The polymer inaccessible pore volume is introduced by the EPHIP card. Polymer inaccessible pore volume is used to model the phenomenon of polymer molecules propagating faster than the solvent for flow in porous media.

EPHIP nep ephip

00 Definition:

nep Polymer property region number corresponding to the values of the IPOLYT array defined by the OVER or VOVER cards (Section 9.6).

ephip Effective polymer porosity normalized by the true porosity, p/.

9.1.7 Cation Exchange Cards (IONEX)

00 The exchange of monovalent and divalent cations between the aqueous phase and

the clays is modeled using electrostatic association (Reference 8). The required parameters are introduced by the following cards.

IONEX nex (card 1)QV XKC (card 2)qv xkc (card 3)

00 Definitions:

IONEX Alpha label indicating that the data being read are cations exchange parameters.

nex Polymer property region number corresponding to the values of the IPOLYT array defined by the OVER or VOVER cards (Section 9.6).


qv Cation exchange capacity of the reservoir rock. (meq/ml of P.V.).

xkc Cation exchange constant (meq/ml)-1.

5000.4.4 9-489


9.1.8 Effective Divalent Salinity Cards (CSEP)

00 Divalent cations affect the polymer properties more than the monovalent cations. An effective divalent salinity is the equivalent monovalent salinity which gives the same polymer properties. In general the effective divalent salinity is a multiple of the divalent salinity. The required parameters are introduced by the following cards.

CSEP (card 1)BETAP CSE1 (card 2)betap cse1 (card 3)

00 Definitions:

CSEP Alpha label indicating that the data being read are effective divalent salinity parameters.


betap Multiplier for the effective divalent salinity (dimensionless).

cse1 Salinity value below which the polymer properties are considered to be independent of salinity (meq/ml).

9.1.9 Salinity Units Card (SUNITS)

00 The electrolyte concentrations can be specified in units of either meq/ml or ppm. (Section 9.6) The SUNITS card indicates which type of unit to use.

SUNITS

MEQ MLPPM

00 The SUNITS card can be used more than once to change the units of the data being read and printed. The default is MEQ/ML.

9-490 5000.4.4


9.2 Injectors

9.2.1 Polymer Concentration (CPINJ)

00 An INJ card specifying the well as a water injector must precede a CPINJ card.

00 The CPINJ card is used to specify the concentration of polymer injected for water injection wells in VIP-POLYMER.

CPINJ wl (card 1)cpw1 cpw2 . . .cpwn (card 2)

00 Definitions:

wl List of wells for which cpw values are being specified (see Section 1.5.2).

cpw Polymer concentration being injected in the well. Units are ppm.

NOTE: The number of cpw values must equal the number of wells in the well list.

9.2.2 Anion (Chloride) Concentration (CLINJ)

00 An INJ card specifying the well as a water injector must precede a CLINJ card.

00 The CLINJ card is used to specify the anion (chloride) concentration for water injection wells in VIP-POLYMER.

CLINJ wl (card 1)clw1 clw2 . . .clwn (card 2)

00 Definitions:

wl List of wells for which clw values are being specified (see Section 1.5.2).

clw Anion concentration of the water being injected in the well. Units are meq/ml (ppm).

NOTE: The number of clw values must equal the number of wells in the well list.

5000.4.4 9-491


9.2.3 Divalent Cation (Calcium) Concentration (CAINJ)

00 An INJ card specifying the well as a water injector must precede a CAINJ card.

00 The CAINJ card is used to specify the divalent cation (calcium) concentration for water injection wells in VIP-POLYMER.

CAINJ wl (card 1)caw1 caw2 . . .cawn (card 2)

00 Definitions:

wl List of wells for which caw values are being specified (see Section 1.5.2).

caw Divalent cation concentration of the water being injected in the well. Units are meq/ml (ppm).

NOTE: The number of caw values must equal the number of wells in the well list.

9.2.4 Polymer Slug Definition (PSLUG)

00 An INJ card specifying the well as a water injector must precede a PSLUG card.

00 The PSLUG card is used to define a polymer slug. A Polymer slug consists of a series of steps. Each step is defined by a polymer concentration and size.

PSLUG well cpw1 size1 (cpw2 size2) ...(cpwn sizen)

00 Definitions:

well Well number or name for which data is being defined.

cpwn Polymer concentration of step n. Units are ppm.

sizen Polymer size of step n. Units are Lb (kg).

9-492 5000.4.4



00 The POLYMER option allows additional FPERF parameters.

FPERF (card 1)WELL ........ (RADBP) (RADWP) ...... (card 2)

........ (radbp) (radwp) ...... (card 3)(Card 3 is repeated as necessary to describe all the perforations for each well being perforated)

00 Definitions:

RADBP Colummn heading for radbp, ft (m), the equivalent radius of the gridblock used for calculating the shear rate effective polymer viscosity. Default is radb, or rb from the RFLOW card. A value less than or equal to zero will result in zero shear rate polymer viscosity for well inflow calculations.

RADWP Colummn heading for radwp, ft (m), the wellbore radius. Default is radw, or rw from the RFLOW card. This value is used for calculating the shear rate effective polymer viscosity for well inflow calculations. A value less than or equal to zero will result in a zero shear rate polymer viscosity.

9.3 Instantaneous Gel Model

00 An aqueous phase containing polymer in the reservoir can be gelled instantaneously provided the polymer concentration is above a certain cut off value. The gelled phase is considered immobile and the initial gel saturation is equal to the water saturation in the gridblock at the time specified. The gelled phase has the same compressibility as the aqueous phase. The water relative permeability in a gridblock containing a gel phase is calculated as follows:

00 krw(Sw) = krw(Sw + Sgel) - krw(Sgel)

00 Polymer and electrolytes are not allowed to flow out of a gridblock that has a gel saturation.

9.3.1 Gel Data (GEL)

GEL (cpgel) (PRINT)

5000.4.4 9-493


00 Definitions:

cpgel Polymer concentration cut off, ppm (Default is 0.0)

PRINT Prints gel saturation array.

NOTE: Both cpgel and PRINT are order dependent.

9.3.2 Permeability Reduction Multiplier (RKMULT)

RKMULT (rkm) (PRINT)

00 Definitions:

rkm Aqueous phase permeability reduction multiplier (Default is 1.0). rkm modifies the current rk as follows:

rk = 1. + (rk - 1) * rkm

PRINT Prints the modified rk array.

NOTE: Both rkm and PRINT are order dependent.

9.4 Print/Map Arrays and Parameters (OUTPUT, MAPOUT)

00 The POLYMER option allows additional arrays for the OUTPUT and/or MAPOUT cards.

OUTPUT array1 . . . arraymMAPOUT array1 . . . arrayk

00 Definitions:

array Alpha label of those arrays being defined on either an OUTPUT card or a MAPOUT card:

CPW Polymer concentration in aqueous phase, ppm.

CPA Adsorbed polymer, lb/ac-ft bulk reservoir.

CPTOT Total polymer concentration on a pore volume basis (ppm).

9-494 5000.4.4


CPTOT = SW * CPW + CPADS

RK Permeability reduction factor.

VISW0 Polymer phase viscosity at zero shear rate, cp.

VISW Effective polymer phase viscosity (includes shear rate effects), cp. This results in the output of 3 arrays: x direction shear, y direction shear and z direction sheer.

SHEAR Shear rate, 1/sec. This results in the output of the 3 directional arrays.

CSEP Effective salinity for calculating the salinity dependent polymer properties, (meq/ml).

NAW Sodium concentration in aqueous phase, (meq/ml).

NAA Adsorbed sodium concentration, (meq/ml P.V.).

NATOT Total sodium concentration, (meq/ml P.V.).

CLW Chlorine concentration in aqueous phase, (meq/ml).

CLTOT Total chlorine concentration, (meq/ml P.V.).

CAW Calcium concentration in aqueous phase, (meq/ml).

CAA Adsorbed calcium concentration, (meq/ml P.V.).

CATOT Total calcium concentration, (meq/ml P.V.).

IPOLYT Polymer properties region index.

5000.4.4 9-495


9.5 Timestep Controls (DT)

00 The POLYMER option allows additional parameters for the DT card.

DT . . . . . . . dcpmax dclmax dcamax

00 Definitions:

dcpmax Maximum change in total polymer concentration allowed during a timestep, ppm. Default is 50 ppm.

dclmax Maximum change in total anion concentration allowed during a timestep, meq/ml pore volume. Default is 0.1 meq/ml.

dcamax Maximum change in total divalent ion concentration allowed during a timestep, meq/ml pore volume. Default is 0.1 meq/ml.

NOTE: 1. The use of dcpmax requires that all values on the DT card, through dzmax, be specified, as defined above.

2. The use of dclmax requires dcpmax to be specified and-the use of dcamax requires dclmax to be specified.

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9.6 Modifying VIP-CORE Array Data

9.6.1 Override Modification (OVER)

00 The following are additional arrays available when the POLYMER option is invoked. Their use and effect is analogous to the normal use of the OVER card (Section 8.6.1).


i1 i2NX

j1 j2NY

k1 k2NZ

#v (v2) (#v (v2)) (#v (v2)) (#v (v2))


00 Definition:


IPOLYT POLYMER properties table pointers.

CLW Anion concentration of the aqueous phase, meq/ml (ppm).

CAW Divalent cation concentration of the aqueous phase, meq/ml (ppm).

9.6.2 Individual Value Override Modification (VOVER)

00 The following are additional arrays available when the POLYMER option is invoked. Their use and effect is analogous to the normal use of the VOVER card.


i1 i2NX

j1 j2NY

k1 k2NZ

(op)

values as necessary

00 Definitions:

array One of the following array names to be defined or altered:

IPOLYT POLYMER properties table pointers.

5000.4.4 9-497


CLW Anion concentration of the aqueous phase, meq/ml (ppm).

CAW Divalent cation concentration of the aqueous phase, meq/ml (ppm).

9-498 5000.4.4

Chapter

10

Surface Pipeline Network Option1

10.1 General Information

The surface pipeline network option may be used to define a production network and/or an injection network. These networks must be independent of each other; i.e. a node may exist in only one network and production and injection wells may not point to the same node.

Before using the injection network option, please read “Understanding Injection Network Allocations and Node Pressures in VIP” on page 10-580.

Input data of the surface pipeline network option can be divided into the following major groups:

1. Profiles of temperature, temperature gradient, inclination angle, valve coefficient, and choke correlation.

2. Pipe, well tubing, and valve data.

3. Link data.

4. Node data. (pressure and rate constraints, partial separation data).

5. Node connection data.

6. Data of well connections to nodes.

7. Satellite oil field production data.

8. Pseudo well modeling.

9. General parameters.

10. Output information.

1. Available as a separately licensed option. Not available in VIP-THERM

5000.4.4 10-499


11. Integration with predictive well management.

12. Production well optimization.

These groups will be described in the following sections.

Surface pipeline network data can be changed during a reservoir simulation after the DATE or TIME card.

Input of some surface pipeline network data is position-dependent. Profile data must precede pipe and well tubing data. Data of the flow devices (BHPTAB, BHITAB, pipe, and well tubing data) must precede link data. Link and flow device data must precede node and well connection data.

The hydraulic tables (BHPTAB or BHITAB) can be used for the description of the multi-phase fluid flow in the flow devices of the surface pipeline network system. Besides, the BHPTAB hydraulic table can be applied for the determination of the pressure gradients in pipelines and well tubing. Input format of the BHPTAB or BHITAB hydraulic tables has not changed. However, their parameters have different definitions, which are described below. An option has been developed to generate five-dimensional hydraulic tables for any well tubing string and/or any connection between nodes of the surface pipeline network system.

Each node of the surface pipeline network system can have any number of input connections. Each node may also have multiple output connections under two possible scenarios:

1. One active connection with additional potential output connections. The simulator can automatically select an output connection if fluid rate drops below a minimum value.

2. Multiple active connections. The fluid volume in each active connection is assigned using splitting factors. No robust hydrodynamic calculations are made for the allocation of the fluid to the connections.

The surface pipeline network model has a general “tree-like” structure with any number of node levels. However, loops can not be included.

As with nodes, wells may be connected to more than one node under two possible scenarios:

1. One active connection with additional potential output connections. The simulator can automatically select a well connection to a node if the NEW predictive well management option is active (PREDICT NEW).

2. Multiple active connections. The fluid volume in each active connection is assigned using splitting factors. No robust hydrodynamic calculations are made for the allocation of the fluid to the connections.

10-500 5000.4.4


The pseudo well option is provided to model some parts of the reservoir or satellite oil fields which are connected to the surface pipeline network system but which are not represented in the reservoir model. Inflow performance correlations are applied for the definition of pseudo well production rates. Most available well management features can be used for these wells.

Names of profiles, pipes, well tubings, valves, links, and nodes can not be longer than eight characters. The first character in the name must be alphabetic unless the name is immediately preceded by the character #.

The simplified heat transfer analysis option applies only to production networks.

When the water salinity option is active, the surface pipeline network option does not take into account any salinity values.

The following gathering system will be used as an example in the keyword descriptions:

Well1 Well4 Well5 Well 6 Well 7

Node1 Node2 Node5

Node3

Node4

tubing1 tubing2 link2 BHPTAB link3

link1

pipe3

pipe1 pipe2

pipe3

pipe6 pipe3Wellhead

5000.4.4 10-501


10.2 Flow Modeling in Well Tubing Strings

All capabilities for modeling of multiphase compositional flow in devices of the surface pipeline network system can be applied for flow modeling in well tubing from a wellbore to a wellhead. Therefore, CURVE, PIPES, TUBING, VALVES, BHPTAB, BHITAB, LINK, and WELCON cards can be applied for flow modeling in well tubing strings. This part of the surface pipeline network option can be used independently from the more general surface pipeline network modeling.

The following data in the specified sequence must be provided to apply these capabilities for flow modeling in well tubing strings:

• tubinghead pressure (THP cards);

• profiles of temperature, temperature gradient, inclination angle, valve coefficient, and choke correlation, if required (CURVE cards);

• hydraulic table, pipe, well tubing, and/or valve data, if required (BHPTAB, BHITAB, PIPES, TUBING, VALVES, and/or LINK cards);

• well tubing connection data (WELCON cards).

Example:

CC In the following example, a well string for Well 1 consists of C 3 tubing sections with different diameters, thicknesses, lengths, C and temperature distributions. They are connected using Link LINK1.C The well string for Well 2 is modeled by tubing TUBIN4.CTHP 1 2

750 750TUBINGSNN NAME DIAMET THICKN ROUGHN LENGTH TEMPUP TEMPDW PDCORR 1 TUBIN1 1.128 0.619 0.00001 590 400 397.3 HAGEDORN 2 TUBIN2 1.375 0.75 0.00001 17501 397.3 316.1 HAGEDORN 3 TUBIN3 1.338 0.820 0.00001 3458 316.1 300 HAGEDORN 4 TUBIN4 1.338 0.820 0.00001 21100 400 300 HAGEDORNLINK 1 LINK1C NN Name Type Num_Drop Pressure_CorrectionIPVT 1 TUBIN1 TUBING 1 0. 2 2 TUBIN2 TUBING 1 10 1 3 TUBIN3 TUBING 1 15 3 WELCONWELL TUBCON TUBCNT WDZ WDAT 1 LINK1 LINK 20500 21000 2 TUBIN4 TUBING 20900 21000C

10-502 5000.4.4


10.3 Application of Hydraulic Tables for Modeling Flow in Flow Devices

Hydraulic tables (BHPTAB or BHITAB) can be used for modeling of the fluid flow in the flow devices of the surface pipeline network system.

The five-dimensional hydraulic table (BHPTAB) defines pressure at the inlet of the flow device (BHP) as a tabular function of pressure at the outlet of this device (THP), liquid rate (QLIQ), gas-oil ratio (GOR), water cut (WCUT), and artificial lift quantity value (ALQ). Alternatively, oil or gas rate (QO or QG) may be used instead of the liquid rate, and gas-liquid or oil-gas ratios (GLR or OGR) may be used instead of the gas-oil ratio, and water-gas ratio (WGR) may be used instead of the water cut. The artificial lift quantity is an additional input variable which may be pipe inclination angle, gas-lift rate, pump efficiency or power, etc.

The two-dimensional hydraulic table (BHITAB) defines pressure at the inlet of the flow device (BHP) as a tabular function of pressure at the outlet of this device (THP) and the liquid or gas rate (QI).

Pressure, temperature, and the PVT table number (in non-thermal problems), which are used for the determination of the volumetric rates, are determined in the LINK card.

10.4 Application of Look-Up Tables for Pressure Gradient Determination in Pipes

A five-dimensional hydraulic table (BHPTAB) can be used for modeling of pressure gradient in different pipe locations. In this case, the hydraulic table BHPTAB defines pressure (BHP) at the beginning of a pipe interval with the specified length (dzw) as a tabular function of the pressure (THP) at the end of this interval, liquid rate (QLIQ), gas-oil ratio (GOR), water cut (WCUT), and inclination angle (ALQ). Alternatively, oil or gas rate (QO or QG) may be used instead of the liquid rate, and gas-liquid or oil-gas ratios (GLR or OGR) may be used instead of the gas-oil ratio, and water-gas ratio (WGR) may be used instead of the water cut.

The pressure gradient at the current pipe location L is calculated as a difference of the pressures at the end and the beginning of a pipe interval divided by the interval length:

dPdL------- L THP BHP–

dzw------------------------------=

5000.4.4 10-503


10.5 Profiles of Temperature, Inclination Angle, Valve Coefficient, Choke Correlation, and PVT Tables (CURVE)

10.5.1 Temperature Profile (CURVE TEMPPR)

A temperature profile determines a temperature distribution in pipes and well tubing. It is used to relate temperature in different pipe locations to variable pipe length.

CURVE TEMPPR tnameLENGTH length1 length2 . . . lengthnTEMP temp1 temp2 . . . tempn

Definitions:

TEMPPR Alpha label indicating that the temperature profile is input.

tname Name of the temperature profile.

LENGTH Alpha label indicating that the values on this card are pipe length values. The values of the pipe length must be input in increasing order.

length Length of the pipe from the inlet to the current position, ft (m).

TEMP Alpha label indicating that the values on this card are temperature values.

temp Temperature in the current pipe position, °F (°C).

NOTE: 1. Values of length and temperature can be input on several cards.

2. The linear interpolation technique is used for the determination of temperature between the entries of the temperature profile.

3. In general, this data defines a fluid temperature profile. But, in the simplified heat transfer analysis option (HEATTR = 1 in the NETPAR card), this data defines an ambient temperature profile.

Examples:

CC Two temperature profiles. CCURVE TEMPPR TEMPPR1LENGTH 0 3000 5000 6000

10-504 5000.4.4


TEMP 150 140 130 120CCURVE TEMPPR TEMPPR3LENGTH 0 8500TEMP 60 160

10.5.2 Temperature Gradient Profile (CURVE TMGRPR)

A temperature gradient profile determines a temperature gradient distribution in pipes and well tubing strings. It is used to relate temperature gradient in different pipe locations to subsea depth.

CURVE TMGRPR tnameDEPTH depth1 depth2 ... depthnTEMP temp1 temp_grad2... temp_gradn

Definitions:

TMGRPR Alpha label indicating that the temperature gradient profile is input.

tname Name of the temperature gradient profile.

DEPTH Alpha label indicating that the values on this card are subsea depths. The values of the subsea depth must be input in increasing order.

depth Subsea depth, ft (m).

TEMP Alpha label indicating that the values on this card are temperature or temperature gradient values.

temp Temperature at the first subsea depth, depth1, °F (°C).

temp_grad Temperature gradient at the current subsea depth, °F/feet (°C/m).

NOTE: 1. Values of subsea depth and temperature gradient can be input on several cards.

2. In general, this data defines a fluid temperature gradient profile. But, in the simplified heat transfer analysis option (HEATTR = 1 in the NETPAR card), this data defines an ambient temperature gradient profile.

5000.4.4 10-505


Example:

CCURVE TMGRPR temgrprDEPTH 0 1369 5962TEMP 60 0.022 0.021

10.5.3 Elevation Profile (CURVE ELEVPR)

An elevation profile relates inclination angle at different pipe locations to the cumulative pipe length from the beginning position of the pipe segment. The beginning position of the pipe is the end of the pipe closest to the well.

CURVE ELEVPR enameLENGTH length1 length2 . . . lengthnANGLE angle1 angle2 . . . anglen

Definitions:

ELEVPR Alpha label indicating that the elevation profile is input.

ename Name of the elevation profile.

LENGTH Alpha label indicating that the values on this card are cumulative pipe lengths. The values of length must be input in increasing order.

length Cumulative length of the pipe from the beginning position of the pipe segment to the position at which the inclination applies, ft (m).

ANGLE Alpha label indicating that the values on this card are inclination angle values.

angle Inclination angle from the horizontal axis at this position of the pipe, degrees (radians).

NOTE: Values of length and inclination angle can be input on several cards.

Examples:

CC Three elevation profiles.CCURVE ELEVPR ELEVPR1LENGTH 2000 3000 4000 5000 6000ANGLE 0 5 8 12 0

10-506 5000.4.4


CCURVE ELEVPR ELEVPR2LENGTH 2000 3000 4000 5000 6000ANGLE 3 5 8.4 12 4CCURVE ELEVPR ELEVPR3LENGTH 4200 8400ANGLE 95 97

10.5.4 Valve Coefficient Profile (CURVE VCPR)

Valve coefficient profile relates valve coefficient in a valve model to valve setting.

CURVE VCPR vname SET set1 set2 . . . setn VC vc1 vc2 . . . vcn

Definitions:

VCPR Alpha label indicating that the valve coefficient profile is input.

vname Name of the valve coefficient profile.

SET Alpha label indicating that the values on this card are valve settings. The values of valve setting must be input in increasing order.

set Valve setting.

VC Alpha label indicating that the values on this card are valve coefficients.

vc Valve coefficient.

NOTE: 1. Values of valve setting and valve coefficient can be input on several cards.

2. The linear interpolation technique is used for the determination of the valve coefficient between the entries of the valve coefficient profile.

Examples:

CC Two “dummy” valve coefficient profiles.CCURVE VCPR VC1

5000.4.4 10-507


SET 1 2 3 4VC 5.4 0.8 0.3 0.01CCURVE VCPR VC2SET 1 2 3 4VC 3.8 2.7 0.8 0.1

10.5.5 Choke Correlation (CURVE IDPR)

Choke correlation relates choke internal diameter in a Perkins choke model to choke setting.

CURVE IDPR cname SET set1 set2 . . . setn ID id1 id2 . . . idn

Definitions:

IDPR Alpha label indicating that the choke correlation is input.

cname Name of the choke correlation.

SET Alpha label indicating that the values on this card are choke settings. The values of choke setting must be input in increasing order.

set Choke setting.

ID Alpha label indicating that the values on this card are choke inner diameters.

id Choke inner diameter, in (cm).

NOTE: 1. Values of choke setting and diameter can be input on several cards.

2. The linear interpolation technique is used for the determination of the choke diameter between the entries of the choke correlation table.

3. Choke correlation must be defined to apply the Perkins choke model. It must be input before the Perkins choke model description in the VALVES card.

Example:

C

10-508 5000.4.4


CC WILLIS 0.75 ChokeC CCURVE IDPR C0201C Choke setting in degreesSET 20.5 21 21.5 22 22.5 23 ..........C Choke inner diameter in inchesID 0.014465 0.034404 0.050908 0.065789 0.079637 0.092741 ......

10.5.6 PVT Property Table Profile (CURVE IPVTPR)

A PVT property table profile determines a relationship between a PVT table number and temperature. It is used to relate fluid PVT properties to temperature in different elements of the surface pipeline network system in black-oil models.

CURVE IPVTPR inameTEMP temp1 temp2 . . . tempnIPVT ipvt1 ipvt2 . . . ipvtn

Definitions:

IPVTPR Alpha label indicating that the PVT property table profile is input.

iname Name of the PVT property table profile.

TEMP Alpha label indicating that the values on this card are temperatures.

temp Temperature, °F (°C). Temperature values must be input in increasing order.

IPVT Alpha label indicating that the values on this card are PVT property table numbers.

ipvt PVT property table number.

NOTE: 1. Temperature values and PVT property table numbers can be input on several cards.

2. The linear interpolation technique is used for the determination of the fluid PVT properties between the temperature entries of the PVT property profile.

Examples:

CC PVT property table profiles. CCURVE IPVTPR PVTPROFI

5000.4.4 10-509


TEMP 52 60 100 200IPVT 4 3 2 1

10.6 Pipe Data (PIPES)

Parameters of horizontal or inclined pipes are input after the PIPES keyword. A five-dimensional hydraulic table (BHPTAB) can be used for the determination of the pressure gradient at different pipe locations instead of the analytical correlations. In this case, the hydraulic table number should be input with a minus sign in the PDCORR column.

PIPES NN param1 param2 . . . paramnnum1 value11 value21 . . . valuen1num2 value12 value22 . . . valuen2...numm value1m value2m . . . valuenm

Definitions:

NN Alpha label indicating that the pipe number is input in this column.

num Pipe number. The pipe numbers must be input in increasing order.

param Alpha labels of those pipe parameters being defined. The following parameters can be input: DIAMETER, THICKNESS, ROUGHNESS, LENGTH, ANGLE, YOUNG, NAME, PRESIN, TEMPUP, TEMPDW, PDCORR, DHCOR, ELEVPR, TEMPPR, TMGRPR, HTC, GRPGCR, FRPGCR, ACPGCR.

DIAMETER Pipe inner diameter, in (cm). This parameter must be input.

THICKNESS Pipe thickness, in (cm). This parameter must be input.

ROUGHNESS Pipe roughness factor, in (mm). This parameter must be input.

10-510 5000.4.4


LENGTH Pipe total length, ft (m). One of the parameters elevation profile (ELEVPR) or pipe total length (LENGTH) must be input. If ELEVPR is input, LENGTH is ignored, in which case the total pipe length is set to the last entry in the LENGTH row of the elevation profile.

ANGLE Pipe inclination angle from the horizontal axis, degrees (radians). This parameter is ignored if pipe elevation profile (ELEVPR) is input. Default is zero.

YOUNG Young modules, million psia (million kPa). The default value of this parameter is defined on the NETPAR card.

NAME Pipe name.

PRESIN Pressure increment, psia (kPa). A second order Runge-Kutta procedure with an automatic selection of integration intervals is applied for the numerical solution of the pipe flow equations. The integration interval is selected to assure that the pressure drop in this interval is not larger than the pressure increment PRESIN. The default value of this parameter is defined on the NETPAR card.

TEMPUP Upstream temperature of the pipe for production, downstream temperature of the pipe for injection, °F (°C). This parameter is ignored if the temperature profile is input. The default value of this parameter is defined on the NETPAR card.

TEMPDW Downstream temperature of the pipe for production, upstream temperature of the pipe for injection, °F (°C). This parameter is ignored if the temperature profile is input. The default value of the parameter is defined on the NETPAR card.

PDCORR Pressure drop correlation for two-phase flow (see Note 1). The following correlations can be used:

NOSLIP without slip effect;

DUKLER Dukler II with Flanigan correction for elevation;

DUKEAT Dukler II with Eaton holdup and Flanigan correction for elevation;

BEGGS Beggs and Brill;

ANSARI Ansari;

5000.4.4 10-511


ANSBEG Ansari, for deviation angle between 45o and 135o and between 225o and 315o (measured from horizontal); Beggs and Brill, otherwise;

-n Use hydraulic table (BHPTAB) number n to determine the pressure gradient in the pipe.

Default is BEGGS.

DHCOR Downhill correction flag. The downhill correction (meaning ignore elevation pressure gradient) is applied if the value of this parameter is one. The downhill correction is not used if a value of zero is input. Only the values zero and one may be entered. Default is zero.

ELEVPR Name of the elevation profile, from the CURVE ELEVPR card.

TEMPPR Name of the temperature profile, from the CURVE TEMPPR card.

TMGRPR Name of the temperature gradient profile, from the CURVE TMGRPR card.

HTC Pipe heat transfer coefficient, BTU/(hr*ft2*0F)( W/(m2*0K)). This parameter is applied only in the simplified heat transfer analysis option (HEATTR = 1 in the NETPAR card). Defaults to HTCPIPE in the NETPAR card.

GRPGCR Correction factor for the gravity pressure gradient.

FRPGCR Correction factor for the friction pressure gradient.

ACPGCR Correction factor for the acceleration pressure gradient.

value The value of the corresponding parameter.

10-512 5000.4.4


NOTE: 1. During the pressure drop calculation, if it is determined that only a single-phase fluid exists (i.e., only gas or only liquid), the NOSLIP correlation will be used. The PDCORR option entered by the user (or defaulted) is only used for two-phase flow.

2. The default values of the pressure gradient correction factors GRPGCR, FRPGCR, and ACPGCR are defined in the NETPAR card. They can be automatically adjusted using the TBADJ or TUNING options.

2. In the simplified heat transfer analysis option (HEATTR = 1 in the NETPAR card), TEMPUP and TEMPDW are ambient temperatures; otherwise they are fluid temperatures.

Examples:

CC Parameters of six pipelines.CPIPESNN NAME DIAMET THICKN ROUGHN PRESIN TEMPUP TEMPDW PDCORR LENGTH1 PIPE1 4. 0.2 0.0001 500 100. 60. BEGGS 100002 PIPE2 4. 0.2 0.0001 500 100. 60. BEGGS 5000CPIPESNN NAME DIAMET THICKN ROUGHN PRESIN TEMPUP TEMPDW PDCORR LENGTH ANGLE3 PIPE3 16 0.2 0.0006 500 100. 60. BEGGS 10000 3CPIPESNN NAME DIAMET THICKN ROUGHN PRESIN ELEVPR TEMPUP TEMPDW PDCORR4 PIPE4 4. 0.2 0.0001 500 ELEVPR1 100 60 DUKLERCPIPESNN NAME DIAMET THICKN ROUGHN PRESIN LENGTH ANGLE TEMPPR PDCORR 5 PIPE5 4. 0.2 0.0001 500 6000 4. TEMPPR2 BEGGSCC Hydraulic table (BHPTAB) with Number 2 is used forC the determination of the pressure gradient in Pipe 6.C PIPESNN NAME DIAMET THICKN ROUGHN PDCORR ELEVPR PRESIN6 PIPE6 4. 0.2 0.0001 -2 ELEVPR1 200

5000.4.4 10-513


10.7 Tubing Data (TUBING)

The parameters of vertical or inclined well tubing are input after the TUBING keyword.

TUBING NN param1 param2 . . . paramn num1 value11 value21 . . . valuen1 num2 value12 value22 . . . valuen2...numm value1m value2m . . . valuenm

Definitions:

NN Alpha label indicating that the well tubing number is input in this column.

num Well tubing number. The well tubing numbers must be input in increasing order.

param Alpha labels of those tubing parameters being defined. The following parameters can be input: DIAMETER, THICKNESS, ROUGHNESS, LENGTH, DEPTH, YOUNG, NAME, PRESIN, TEMPUP, TEMPDW, PDCORR, ELEVPR, TEMPPR,TMGRPR, HTC, GRPGCR, FRPGCR, ACPGCR.

DIAMETER Well tubing inner diameter, in (cm). This parameter must be input.

THICKNESS Well tubing thickness, in (cm). This parameter must be input.

ROUGHNESS Well tubing roughness coefficient, in (mm). This parameter must be input.

LENGTH Well tubing total length, ft (m). One of the parameters elevation profile (ELEVPR), total length (LENGTH), or subsea depth (DEPTH) must be input. If the ELEVPR is input, LENGTH is ignored, in which case the total length is set to the last entry in the LENGTH row of the elevation profile. The total length is assumed to be the true vertical length if on ly the true vertical length is input. The tubing inclination angle is calculated using values of the true vertical length and total length, if the elevation profile is not input.

10-514 5000.4.4


DEPTH True vertical length of well tubing, ft (m). That is, this is the length of the projection of the tubing onto the vertical axis. The value will always be less than or equal to LENGTH. This parameter is ignored if the elevation profile is input. The true vertical length is assumed to be the total length if only the total length is input. The tubing inclination angle is calculated using the true vertical length and total length if the elevation profile is not input.

YOUNG Young modules, million psia (million kPa). The default value of this parameter is defined on the NETPAR card.

NAME Well tubing name.

PRESIN Pressure increment, psia (kPa). A second order Runge-Kutta procedure with an automatic selection of integration intervals is applied for the numerical solution of the pipe flow equations. The integration interval is selected to assure that the pressure drop in this interval is not larger than the pressure increment PRESIN. The default value of this parameter is defined on the NETPAR card.

TEMPUP Upstream temperature of the well tubing for production, downstream temperature of the well tubing for injection, °F (°C). This parameter is ignored if the temperature profile is input. The default value of this parameter is defined on the NETPAR card.

TEMPDW Downstream temperature of the well tubing for production, upstream temperature of the well tubing for injection, °F (°C). This parameter is ignored if the temperature profile is input. The default value of this parameter is defined on the NETPAR card.

PDCORR Pressure drop correlation for two-phase flow (see Note 1). The following correlations can be used:

NOSLIP without slip effect;

HAGEDORN Hagedorn and Brown;

DUNROS Duns and Ross;

BEGGS Beggs and Brill;

AZIZ Aziz and Govier;

ORKISZEWSKI Orkiszewski;

GRIFFITH Griffith, Lau, Hon, and Pear-son;

5000.4.4 10-515


NOTE: 1. During the pressure drop calculation, if it is determined that only a single-phase fluid exists (i.e., only gas or only liquid), the NOSLIP correlation will be used. The PDCORR option entered by the user (or defaulted) is only used for two-phase flow.

2. The default values of the pressure gradient correction factors GRPGCR, FRPGCR, and ACPGCR are defined in the NETPAR card. They can be automatically adjusted using the TBADJ or TUNING options.

HAG-BEG Hagedorn and Brown, for deviation angle between 45o and 135o and between 225o and 315o (measured from horizontal); Beggs and Brill, otherwise;

ANSARI Ansari;

ANSBEG Ansari, for deviation angle between 45o and 135o and between 225o and 315o (measured from horizontal); Beggs and Brill, otherwise;

-n Use hydraulic table (BHPTAB) number n to determine the pressure gradient in the pipe.

Default is BEGGS.

ELEVPR Name of the elevation profile, from the CURVE ELEVPR card.

TEMPPR Name of the temperature profile, from the CURVE TEMPPR card.

TMGRPR Name of the temperature gradient profile, from the CURVE TMGRPR card.

HTC Tubing heat transfer coefficient, BTU/(hr*ft2*0F) (W/(m2*0K)). This parameter is applied only in the simplified heat transfer analysis option (HEATTR = 1 in the NETPAR card). Defaults to HTCTUB in the NETPAR card.

GRPGCR Correction factor for the gravity pressure gradient.

FRPGCR Correction factor for the friction pressure gradient.

ACPGCR Correction factor for the acceleration pressure gradient.


10-516 5000.4.4


3. In the simplified heat transfer analysis option (HEATTR = 1 in the NETPAR card), TEMPUP and TEMPDW are ambient temperatures; otherwise they are fluid temperatures.

Examples:

CC Well tubing parameters.CTUBINGNN NAME DIAMET THICKN ROUGHN PRESIN DEPTH LENGTH TEMPPR PDCORR1 TUBIN1 4. 0.2 0.0001 500 8400 8500 TEMPPR2 ORKISZ

TUBINGNN NAME DIAMET THICKN ROUGHN PRESIN ELEVPR TEMPUP TEMPDW 2 TUBIN2 4. 0.2 0.0001 400 ELEVPR3 160 60

5000.4.4 10-517


10.8 Valve Data (VALVES, VALSET)

Valve or choke parameters are input after the VALVES card. The VALVEC valve model or PERKINS choke model can be applied.

The VALVEC valve model predicts subcritical pressure drop across a valve using

the following equation6,7:

pout pin– CVX X –Qtot Qtot

-----------------------=

where:

pout is the pressure at the outlet of the valve in psia (kPa);

pin is the pressure at the inlet of the valve in psia (kPa);

Qtot is the total mass rate of the fluid in lb. per sec., which is calculated as a sum of the mass rates of the oil, gas, and water phases;

is the density of the mixture in lb. per cu.ft.

CVX(X) is the valve coefficient which depends on a valve setting X. The user should define the valve coefficients for the different valve settings using a valve coefficient profile (CURVE VCPR).

The oil, gas, or liquid mass rate can be used (instead of the total mass rate) for the definition of the pressure drop in a valve.

The PERKINS choke model represents critical and sub-critical multiphase fluid flow across a choke. The following input is required to apply the Perkins choke model:

1. Input a choke correlation which relates choke setting with choke inner diameter after the CURVE IDPR card.

2. Define the PERKINS model, a choke correlation name, and inner diameter of tubing segment with embedded choke using keywords MODEL, IDPR, and TUBID.

3. Apply choke model in well connections to nodes, node connections, or links.

A pressure control valve or a flow control valve is simulated as follows: The pressure control valve model automatically selects the valve coefficient CVX or the choke setting from a specified range. This coefficient or choke setting minimizes the absolute value of the difference between a valve upstream pressure and a target pressure. The valve coefficient range is defined by a valve coefficient profile and a valve status. If the valve status is “OPEN”, the whole range of the valve coefficient profile is used in the calculations. If the valve status is

10-518 5000.4.4


“CLOSE”, the valve coefficient range consists only from the first entry of the valve coefficient profile. In the flow control valve model, the valve coefficient is defined as one of the end points of the valve coefficient profile. If the valve status is “OPEN”, the valve coefficient is determined as the last entry in the valve coefficient profile. If the valve status is “CLOSE”, the valve coefficient is selected as the first entry in the valve coefficient profile. In the flow control valve/choke, the valve/choke setting can be input in the VALSET card.

VALVES NN param1 param2 . . . paramnnum1 value11 value21 . . . valuen1num2 value12 value22 . . . valuen2..numm value1m value2m . . . valuenm

Definitions:

NN Alpha label indicating that the valve number is input in this column.

num Valve number. The valve numbers must be input in increasing order.

param Alpha labels of those valve parameters being defined. The following parameters can be input: NAME, MODEL, IDPR, TUBID, TEMPUP, TEMPDW, VCPR, TYPE, CONTROL, TARGET, STATUS, MAXPRD.

NAME Valve name.

MODEL VALVEC valve model (default) or PERKINS choke model.

IDPR Name of the choke correlation from the CURVE IDPR card. This parameter must be defined if the PERKINS model is used.

TUBID Inner diameter of a tubing segment with choke, in (cm). This parameter must be defined if the PERKINS model is used.

TEMPUP Upstream temperature of the valve for production, downstream temperature of the valve for injection, °F (°C). The default value of this parameter is defined on the NETPAR card.

TEMPDW Downstream temperature of the valve for production, upstream temperature of the valve for injection, °F (°C). The default value of this parameter is defined on the NETPAR card.

5000.4.4 10-519


Examples:C Valve parameters.VALVESNN NAME TEMPUP TEMPDW CONTROL STATUS VCPR TYPE TARGET1 VALVE1 20. 14.4 PRESUP OPEN VC1 OIL 2000.2 VALVE2 20. 14.4 PRESUP CLOSE VC2 OIL 70.C Choke parameters.VALVESNN NAME MODEL IDPR TUBID TEMPUP TEMPDW 3 W0001C PERKINS C0201 5.875 172 172

VALSET valve_name1 valve_setting1valve_name2 valve_setting2.. ..

VCPR Name of the valve coefficient profile from the CURVE VCPR card. This parameter must be defined if the VALVEC model is used.

TYPE Valve type. One of the following mass rates is used to calculate the pressure drop in the valve:

OIL;

GAS;

LIQUID;

ALL.

Default is ALL.

CONTROL Valve control. A pressure control valve or a flow control valve can be simulated as follows:

PRESUP;

FLOW.

Default is FLOW. The target pressure must be input if the pressure control option is used.

TARGET Target pressure, psia (kPa). This parameter is used only in the valve or choke model with the upstream pressure control.

STATUS Valve status: CLOSE or OPEN. Default is CLOSE.

MAXPRD Maximum pressure drop in a choke/valve, psia (kPa). Default is 2000 psia.


10-520 5000.4.4


Definitions:

valve_name Valve/choke name or number. It must be defined in the VALVES card before it can be referenced in the VALSET card.

valve_setting Valve/choke setting. It is used only if the FLOW valve control is defined in the VALVES card.

5000.4.4 10-521


10.9 Link Data (LINK)

A link simulates the flow of the multi-phase fluids in

• well tubing and casing,

• connections between wellheads and nodes of the surface pipeline network system, and

• connections between nodes.

Each link has only one inlet and one outlet. A link can be constructed from several flow device models sequentially connected with each other. The following models of the flow devices can be used in the link:

• pipe,

• well tubing,

• valve,

• five-dimensional hydraulic table (BHPTAB),

• two-dimensional hydraulic table (BHITAB) with the liquid rate as input variable (BHLTAB),

• two-dimensional hydraulic table (BHITAB) with the gas rate as input variable (BHVTAB).

If the hydraulic tables are applied for the determination of the pressure drop in some flow device included in the link, the volumetric rates are determined from flash calculations. Pressure, temperature, and PVT table number, which are used in these calculations, can be input on the LINK card.

LINK link_number (link_name)

1 nm1 tp1 num1 pcor1 ipvt1 alq1 temp1 pres1

IBAT ibat1 alq1

(IPVTW ipvtw1)

.

.n nmn tpn numn pcorn

ipvtn alqn tempn presnIBAT ibatn alqn

(IPVTW ipvtwn)

Definitions:

link_number Link number. The link numbers should be input in increasing order.

link_name Link name.

10-522 5000.4.4


n Sequential number of the flow device. All flow devices in the link must be numbered starting from the upstream link inlet.

nm Flow device name or number. A value of the NN or NAME parameter in the PIPES, TUBING, or VALVES card should be input in this column. Or, a hydraulic table number (nbhp or nbhi) from the BHPTAB or BHITAB card can be used.

tp Flow device type:

PIPE;

TUBING;

VALVE;

BHPTAB;

BHLTAB (the BHITAB hydraulic table with the liquid rate as the input variable);

BHVTAB (the BHITAB hydraulic table with the vapor rate as the input variable).

num The determination of the pressure drop on the flow device is sequentially repeated num times. Default is one.

pcor Additive pressure correction to apply to the value of pressure at the upstream inlet of the flow device, psia (kPa). Default is zero.

ipvt Flash calculations in the flow device are performed using the "table" ipvt.For black-oil models, ipvt is a PVT property table number or a PVT property profile name (CURVE IPVTPR).For compositional models, ipvt is an equation-of-state table number.For models using EOSINT, ipvt is an EOSINT table number (equilibrium region number).For device types BHPTAB, BHLTAB, and BHVTAB, the default is to assign Separator 1 if it has been defined or the default separator for PVT region 1 if it has not been defined.If the first flow device in the link is PIPE, TUBING, or VALVE, default is one. For all other devices of these types in the link, default is the PVT table number of the previous device.

5000.4.4 10-523


IBAT Alpha label designating that the separator battery model is to be used for the determination of volumetric rates instead of a PVT table or an equation-of-state. This parameter is used only in a model of a flow device described by the hydraulic table (BHPTAB or BHITAB).

ibat Separator battery number. Alternatives include the battery number of a separator input in the separator data (Surface Separator Data), or a value of -npvt which accesses a default separator. This parameter must follow the IBAT alpha label.

alq Artificial lift quantity. This parameter is used only in a model of the flow device described by the hydraulic table (BHPTAB or BHITAB). Default is zero.

temp Temperature applied in flash calculations for the determination of volumetric rates, °F (°C). This parameter is used only in a model of a flow device described by the hydraulic table (BHPTAB or BHITAB). The default value of this parameter is defined on the NETPAR card.

pres Pressure applied in the flash calculations for the determination of volumetric rates, psia (kPa). This parameter is used only in a model of a flow device described by the hydraulic table (BHPTAB or BHITAB). The default value of this parameter is defined on the NETPAR card.

IPVTW Alpha label designating that a water PVT table number or a water PVT profile name is to be read.

ipvtw Water PVT property table number or water PVT property profile name (Section 10.15.1) from which water PVT calculations in the flow device are performed. For the first flow device in the link, default is one. For all other devices in the link, default is the table number or profile name of the previous device.

10-524 5000.4.4


Examples:

CC Link definitions.CLINK 1 LINK1C NN Name Type Numberr_Devices Pressure_Correction 1 PIPE4 PIPE 1 0. 2 PIPE5 PIPE 2 2. 3 VALVE1 VALVE 2 5.LINK 2 LINK2 1 1 BHPTAB 1 0LINK 3 LINK3 1 1 BHLTAB 1 10.LINK 4 LINK4 1 1 BHPTAB 1 0. IBAT -1

5000.4.4 10-525


10.10 Node Data (NODES)

The following information about nodes of the surface pipeline network system are input after the NODES keyword:

• node name and number,

• name and level of the “normal” VIP well management structure (gathering center, flow station, area, or field) which corresponds to the node,

• pressure system assigned to the node,

• number of a separator battery attached to the node,

• rate and pressure constraints at the node,

• parameters of a partial fluid separation in the node.

NOTE: Before using the injection network option, please read “Understanding Injection Network Allocations and Node Pressures in VIP” on page 10-580.

NODES NN param1 param2 . . . paramnnum1 value11 value21 . . . valuen1num2 value12 value22 . . . valuen2..numm value1m value2m . . . valuenm

Definitions:

NN Alpha label indicating that the node number is input in this column.

num Node number. The node numbers must be input in increasing order.

param Alpha labels of those node parameters being defined. The following parameters can be input: NAME, WMN, WML, PRSYS, IBAT, QO, QG, QW, QL, PMIN, PMAXI, TEMP, QOMIN, QGMIN, FRO, FRG, FRW, FRGFO, GASSPM, REMOVE, REINJ, PTARG. See Section 10.19.5 for additional parameters related to the well optimization option.

NAME Node name.

10-526 5000.4.4


WMN Name or number of the gathering center, flow station, area, or field which corresponds to the node. Default is zero.

WML Level of the VIP well management structure which corresponds to the node:

GATHER Gathering Center;

FLOSTA Flow Station;

AREA Area;

FIELD Field.

Default value is GATHER.

PRSYS Name or number of the pressure system assigned to the node. This parameter is applicable only if the predictive well management option (PREDICT NEW) is used. Default is one.

IBAT Number of the separator battery attached to the node. The corresponding separator battery model is used for the determination of the fluid volumetric rates at the node. If a negative value is input, the default separator is used. Default is one if separator battery one is defined. Otherwise, default is -1.

QO Maximum produced oil rate at the node, STB/D (STM3/D). Default is 1.E+15.

QG Maximum produced or injected gas rate at the node, MSCF/D (SM3/D). Default is 1.E+15.

QW Maximum produced or injected water rate at the node, STB/D (STM3/D). Default is 1.E+15.

QL Maximum produced liquid rate at the node, STB/D (STM3/D). Default is 1.E+15.

PMIN Minimum pressure for production nodes, psia (kPA). Default is -1.E+9, meaning no constraint. Input value must not be less than 14.7 psia.

PMAXI Maximum pressure for injection nodes, psia(KPA). Default is 1.E+9.

TEMP Fluid temperature in the node, oF (oC), for the simplified heat transfer analysis option (HEATTR = 1 in the NETPAR card). This value replaces the internally calculated value of fluid temperature.

5000.4.4 10-527


QOMIN Minimum oil rate at the node, STB/D (STM3/D). If the oil rate in the node outlet is less than the minimum value and potential node connections (OUTCN2, etc.) are defined in the NODCON card, then the active node connection can be automatically changed. Only potential node connections will be considered. Next potential connection will be selected as the active connection if pressure in the corresponding output node is less than pressure in the current output node. Default is -1.E+9.

QGMIN Minimum gas rate at the node, MSCF/D (SM3/D). If the gas rate in the node outlet is less than the minimum value and potential node connections (OUTCN2, etc.) are defined in the NODCON card, then the active node connection can be automatically changed. Only potential node connections will be considered. Next potential connection will be selected as the active connection if pressure in the corresponding output node is less than pressure in the current output node. Default is -1.E+9.

FRO Fraction of the oil rate in the node inlet supplied to the node outlet. The inlet oil rate is calculated using the separator model (IBAT) assigned to the node. It is assumed that the remaining fraction (1-FRO) of the inlet oil rate is partially separated in the node. Default is one.

FRG Fraction of the gas rate in the node inlet supplied to the node outlet. The inlet gas rate is calculated using the separator model (IBAT) assigned to the node. It is assumed that the remaining fraction (1-FRG) of the inlet gas rate is partially separated in the node. Default is one.

FRW Fraction of the water rate in the node inlet supplied to the node outlet. It is assumed that the remaining fraction (1-FRW) of the inlet water rate is partially separated in the node. Default is one.

FRGFO Oil rate fraction. If FRGFO is entered, the gas rate in the node outlet is calculated as the FRGFO fraction times the oil rate in the node inlet. The outlet gas rate is also limited by the inlet gas rate. If both FRG and FRGFO fractions are input, then the gas rate in the node outlet is determined as the maximum value of the inlet gas rate multiplied by FRG and the inlet oil rate multiplied by FRGFO.

10-528 5000.4.4


Examples:

CC Node parameter input.C NODESNN NAME IBAT PMIN 1 NODE1 1 -1.E+9 2 NODE2 2 -1.E+9 3 NODE3 1 1620.

GASSPM Maximum rate of gas that can be partially separated in the node, MSCF/D (SM3/D). All gas in excess of the maximum gas separation capacities is supplied to the output flow line of the node. Default value is 1.E+15.

REMOVE Well rate modifier indicator. If YES is entered and the node is assigned to a well management level using keywords WML and WMN, then gas rates and/or water rates of all production wells connected to the node will be adjusted for targeting calculations taking into account gas and/or water partial separation in the node. The REMOVE YES option can be applied only in the node assigned to the gathering center (GATHER) well management level. Default is NO, meaning that the well production rates are not to be adjusted.

REINJ Gas re-injection indicator. If YES is entered and the node is assigned to a well management level using keywords WML and WMN, then gas partially separated in the node will be available for re-injection in the corresponding well management level. The REINJ YES option can be applied only in the node assigned to the gathering center (GATHER) well management level. Default is NO.

PTARG YES indicates that any constraints specified in this NODES data (parameters QO, QG, QW, QL) are interpreted as if read on PTARG cards (Section 4.3.1.) The well management level and number are specified using parameters WML and WMN, respectively. The parameter WMN is required when PTARG is entered. A gas production constraint entered in this manner includes gas lift gas unless the GASLIF parameter on the NETPAR card (Section 10.17) is set to zero. The value NO indicates to use the standard surface pipeline network algorithm. NO is the default if the PTARG parameter is not entered.


5000.4.4 10-529


CNODESNN NAME QO QL 4 NODE4 26500 1.E+15CC Gas partial separation in Node 5.C NODESNN NAME WMN WML IBAT FPG GASSPM REMOVE QL 5 NODE5 1 GATHER 3 0.2 20000 YES 3000

10.10.1 Gas Partial Processing Optimization (PPOPT)

A gas partial processing optimization procedure is implemented. The procedure is executed in the first num_out outer iterations of the next timestep after input of the PPOPT card. An optimum fraction of gas supplied to an output flow line of each node with partial processing is determined. This fraction is applied in timesteps between the partial processing optimization calculations. The optimum gas fraction is determined minimizing an objective function subject to constraints on maximum amount of the separated gas and minimum fraction of gas supplied to the node output flow line. The objective function is determined as a linear combination of the field oil, gas, and water rates with the user-supplied coefficients. The optimum control problem is sequentially solved for each node for which GASSPM and FRG/FRGFO data was entered in the NODES card.

The PPOPT card must be input to apply the gas partial processing optimization procedure. The coefficients of the objective function and number of outer iterations in which the optimization procedure is executed are input in this card. If PPOPT OFF is input, the optimum partial separation fractions, calculated in the previous execution of the optimum gas partial processing optimization procedure, will be ignored, and the “normal” partial processing algorithm will be executed.

PPOPT ON num out oil coef gas coef water coef

OFF

Definitions:

num_out Number of outer iterations in which the partial processing optimization will be executed.

oil_coef Coefficient of field oil production term in the objective function.

gas_coef Coefficient of field gas production term in the objective function.

10-530 5000.4.4


Example:

CC Execute the partial processing optimization procedure in C three outer iterations of the next time step. C Use field oil production as the objective function.

PPOPT ON 3 1 0 0

water_coef Coefficient of field water production term in the objective function.

5000.4.4 10-531


10.11 Node Connection Data (NODCON)

The NODCON card is used to define output connections for each node of the surface pipeline network model.

NODCON NODE param1 param2 . . . paramnnm1 value11 value21 . . . valuen1nm2 value12 value22 . . . valuen2...nmm value1m value2m . . . valuenm

Definitions:

NODE Alpha label indicating that this column will contain a name or number of a node.

nm Name or number of the node. A value of NN or a NAME parameter previously defined in the NODES card should be used in this column.

param Alpha labels of those node parameters being defined. The following parameters can be input: OUTCON, OUTNOD, OUTCNT, SPFCT, OUTCN2, OUTND2, OUTCT2, SPFCT2, OUTCN3, OUTND3, OUTCT3, SPFCT3, OUTCN4, OUTND4, OUTCT4, SPFCT4, OUTCN5, OUTND5, OUTCT5, SPFCT5, OUTCN6, OUTND6, OUTCT6, SPFCT6, IPVT, IPVTW.

OUTCON Name or number of the output connection. A value of NN or a NAME parameter from the PIPES, TUBING, or VALVE cards should be used in this column. Also, a link name (link_name) or number (link_number) from the LINK card can be input.

OUTNOD Name or number of the output node. A value of NN or a NAME parameter from the NODES card should be used in this column. The output connection defined in column “OUTCON” links the node from column “NODE” and the node from column “OUTNOD”.

OUTCNT Output connection type:

PIPE,

TUBING,

VALVE,

LINK.

10-532 5000.4.4


Default is PIPE.

SPFCT Fluid splitting factor for the output connection. Default is 1.

OUTCNi,i = 2, 3, 4, 5, 6

Name or number of additional output connections. A value of NN or a NAME parameter from the PIPES, TUBING, or VALVE cards should be used in this column. Also, a link name (link_name) or number (link_number) from the LINK card can be input.

OUTNDi,i = 2, 3, 4, 5, 6

Name or number of additional output nodes. A value of NN or a NAME parameter from the NODES card should be used in this column. The output connection defined in column “OUTCNi” links the node from the column “NODE” and the node from column “OUTNDi”.

OUTCTi, Type of additional output connections.i = 2, 3, 4, 5, 6

PIPE,

TUBING,

VALVE,

LINK.

Default is PIPE.

SPFCTi,i = 2, 3, 4, 5, 6

Fluid splitting factor for the output connections. A non-zero value indicates the output connection is active. The non-zero splitting factors are normalized to the value one. Default is zero.

IPVT Flash calculations in the output connection are performed using the "table" ipvt.For black-oil models, ipvt is a PVT property table number or a PVT property profile name (CURVE IPVTPR).For compositional models, ipvt is an equation-of-state table number.For models using EOSINT, ipvt is an EOSINT table number (equilibrium region number).Default is one.

IPVTW Water PVT property table number or water PVT property profile name (Section 10.15.1) from which water PVT calculations in the output connection are performed. Default is one.


5000.4.4 10-533


Examples:

CC Nodes connection input.CNODCONNODE OUTNOD OUTCON OUTCNT NODE1 NODE3 PIPE1 PIPENODE2 NODE3 PIPE2 PIPENODE3 NODE4 3 PIPECC Node connection switching in Node 5CNODESNN NAME PMIN IBAT QOMIN 4 NODE4 650 1 -1.E+9 5 NODE5 -1.E+9 1 10000. 6 NODE6 165 2 -1.E+9CC “Active” and “potential” connections for Node 5.CNODCONNODE OUTNOD OUTCON OUTND2 OUTCN2 NODE5 4 PIPE3 NODE6 PIPE3

10-534 5000.4.4


10.12 Lift Gas Composition (YINJA)

The YINJA card is used to specify the lift gas composition for production wells.

It is assumed that the DISSOL fraction of the gaslift gas has the composition specified in the YINJA card. The composition of the other part of the gaslift gas is assumed to be equal to the composition of the produced gas. The DISSOL fraction can be input in the WELCON card(s).

YINJA wlyinja1 yinja2... yinjanc

Definitions:

wl List of production wells for which lift gas compositions are being specified (see Section 1.5.2).

yinjak The mole fraction of component k in the lift gas stream. A value must be specified for each of the components and the values must sum exactly to 1.0.

5000.4.4 10-535


10.13 Well Connection Data (WELCON)

Data of well connections are input after the WELCON keyword, including tubing connections (from wellbore to wellhead) and well connections to nodes of the surface pipeline network system.

WELCON WELL param1 param2 . . . paramn wn1 value11 value21 . . . valuen1wn2 value12 value22 . . . valuen2...wnm value1m value2m . . . valuenm

Definitions:

WELL Alpha label indicating that a name or number of a production or injection well is input in this column.

wn Name or number of a production or injection well.

param Alpha labels of those node parameters being defined. The following parameters can be input: TUBCON, TUBCNT, IPVTTB, WDZ, WDAT, WELHEAD, OUTCON, OUTNOD, OUTCNT, SPFCT, OUTCN2, OUTCN3, OUTCN4, OUTCN5, OUTCN6, OUTND2, OUTND3, OUTDN4, OUTND5, OUTND6, OUTCT2, OUTCT3, OUTCT4, OUTCT5, OUTCT6, SPFCT2, SPFCT3, SPFCT4, SPFCT5, SPFCT6, GLVDZ, DISSOL, IPVTOC, BHTEMP, THTEMP, IPVTWT, IPVTWC.

TUBCON Name or number of well tubing connection:

A value of NN or a NAME parameter from the PIPES, TUBING, or VALVE card;

A link name (link_name) or number (link_number) from the LINK card.

TUBCNT Tubing connection type:

PIPE,

TUBING,

VALVE,

LINK.

Default is TUBING.

10-536 5000.4.4


IPVTTB Flash calculations in the well tubing are performed using the "table" ipvt.For black-oil models, ipvt is a PVT property table number or a PVT property profile name (CURVE IPVTPR).For compositional models, ipvt is an equation-of-state table number.For models using EOSINT, ipvt is an EOSINT table number (equilibrium region number).Default is one.

WDZ Subsea depth of the first perforation, ft (m).

WDAT Subsea depth to which the flowing bottomhole pressure is referenced, ft (m).

WELHEAD Wellhead subsea depth, ft (m). A negative value should be input if a depth above sea level is desired.

OUTCON Name or number of the output connection. A value of NN or a NAME parameter from the PIPES, TUBING, or VALVE cards should be used in this column. Also, a link name (link_name) or number (link_number) from the LINK card can be input.

OUTNOD Name or number of the output node. A value of the NN or a NAME parameter from the NODES card should be used in this column. The output connection defined in column “OUTCON” links the well from column “WELL” and the node from column “OUTNOD”.

OUTCNT Output connection type:

PIPE,

TUBING,

VALVE,

LINK.

Default is PIPE.

SPFCT Fluid splitting factor for the output connection. Default is one.

OUTCNi, i=2,3,4,5,6

Name or number of additional output connections. A value of NN or a NAME parameter from the PIPES, TUBING, or VALVE cards should be used in this column. Also, a link name (link_name) or number (link_number) from the LINK card can be input.

5000.4.4 10-537


OUTNDi, i=2,3,4,5,6

Name or number of additional output nodes. A value of NN or a NAME parameter from the NODES card should be used in this column. The i-th output connection defined in column “OUTCN(i)” links the well from column “WELL” and the node from column “OUTND(i)”.

OUTCTi, i=2,3,4,5,6

Type of additional output connections:

PIPE,

TUBING,

VALVE,

LINK.

Default is PIPE.

SPFCTi, i=2,3,4,5,6

Fluid splitting factor for the output connection. A non-zero value indicates the output connection is active. The non-zero splitting factors are normalized to the value one. Default is zero.

GLVDZ Subsea depth of the gaslift valve, ft (m).

DISSOL Percent of the lift gas that dissolves in the well fluid.

IPVTOC Flash calculations in the output connections are performed using the "table" ipvt.For black-oil models, ipvt is a PVT property table number or a PVT property profile name (CURVE IPVTPR).For compositional models, ipvt is an equation-of-state table number.For models using EOSINT, ipvt is an EOSINT table number (equilibrium region number).Default is one.

BHTEMP Bottomhole temperature, 0F (oC). This parameter is used only if the heat transfer analysis is applied for the determination of the temperature distribution in well tubing string. Default is an ambient temperature in the well bottomhole.

THTEMP Tubinghead temperature, 0F (oC). This parameter is used for injection wells only if the heat transfer analysis is applied for the determination of the temperature distribution in well tubing string. If this parameter is entered, the BHTEMP parameter is ignored.

10-538 5000.4.4


NOTE: When the WELCON card is used in combination with the ITUBE/TUBE card for a production or injection well, the dzw parameter on the ITUBE/TUBE card means subsea depth of the first perforation.

NOTE: Well “potential” connections OUTND(i), i=2,3,4,5,6 are applied only if the surface pipeline network option is used in combination with the predictive well management option (PREDICT NEW). In this case, the predictive well management option is used for the well allocation to the pressure systems. Well connections to nodes are automatically modified after the well allocation to the pressure systems. Well management levels and pressure systems must be defined for all “potential” nodes in the NODES cards using keywords WML, WMN, and PRSYS.

Examples:

CC Well connection input.CWELCON WELL TUBCON TUBCNT OUTNOD OUTCON OUTCNT 1 TUBIN1 TUBING NODE1 LINK1 LINK 4 TUBIN2 TUBING NODE2 PIPE5 PIPE 5 LINK2 LINK NODE3 LINK1 LINKCC “Active” and “potential” connections of Well 7.CWELCON WELL TUBCON TUBCNT OUTNOD OUTCON OUTND2 OUTCN2 7 LINK3 LINK NODE5 PIPE3 NODE2 PIPE3 CC Flow in tubing of Well 6 is described by Hydraulic Table 1.CITUBE 618335

IPVTWT Water PVT property table number or water PVT property profile name (Section 10.15.1) from which water PVT calculations in the well tubing are performed. Default is one.

IPVTWC Water PVT property table number or water PVT property profile name (Section 10.15.1) from which water PVT calculations in the output connections are performed. Default is one.


5000.4.4 10-539


WLWDAT 68300CWELCONWELL OUTNOD OUTCON OUTCNT 6 NODE5 PIPE6 PIPECC 2 "active" connections with equal fluid distributions of well 8.CWELCONWELL TUBCON TUBCNT OUTNOD OUTCON OUTND2 OUTCN2 SPFCT28 LINK3 LINK NODE5 PIPE3 NODE2 PIPE3 1.0

10-540 5000.4.4


10.14 Satellite Field Production Data (NODSOURCE and SOUCOM)

In some cases, production from several reservoir oil fields are processed in shared surface facilities. An option has been implemented to represent production from satellite oil fields in integrated reservoir and surface pipeline network modeling. Oil, gas, and water rates of the satellite oil fields and their fluid compositions can be input as functions of time using the NODSOURCE and SOUCOM cards. Satellite production modeling impacts pressure drop calculations in flow lines and the targeting procedure in different well management levels, because satellite production increases the amount of fluids supplied to pipelines and different levels of the well management structure.

NODSOURCENODES node1 node2 . . . noden (OIL oil_rate1 oil_rate2 . . . oil_raten)(GAS gas_rate1 gas_rate2 . . . gas_raten)(WATER water_rate1 water_rate2 . . . water_raten)

Definitions:

node Name or number of a node to which a satellite field is connected. The node must have been defined in the NODES card as a value of NN or a NAME parameter.

oil_rate Oil rate of the satellite field connected to the node, STB/D (STM3/D).

gas_rate Gas rate of the satellite field connected to the node, MSCF/D (SM3/D).

water_rate Water rate of the satellite field connected to the node, STB/D (STM3/D).

NOTE: If some node with satellite connections is assigned to a well management level using keywords WML and WMN in the NODES card, the satellite production will be added to the production in this level and all higher levels. Otherwise, the satellite production will not be added to the production in different well management levels and it only impacts pressure drop calculations in flow lines.

5000.4.4 10-541


Example:

NODSOURCE NODES NODE1 OIL 8537 GAS 18636 WATER 5751

SOUCOM nodecomp1 comp2 . . . compnc

Definitions:

node Name or number of a node to which a satellite field is connected. The node must have been defined in the NODES card as a value of NN or a NAME parameter.

compk Molar fraction of the k-th hydrocarbon component in satellite field fluids, fraction.

NOTE: NC molar fractions must be input. They can be input in several lines. The sum of the molar fractions must be equal to one.

Example:

SOUCOM NODE1 0.0059000 0.4185992 0.0444999 0.0318999 0.0124000 0.0157 0.0179 0.0803058 0.1127808 0.0882468 0.1085218 0.0632459

10-542 5000.4.4


10.15 Production Fluids from Different PVT Units

Production fluids from different PVT regions (PVT units) are modeled in the surface pipeline network.

10.15.1 Water PVT Profile (SPNPVW)

The SPNPVW card is used to define a water PVT profile. Water density and viscosity are a function of pressure and, optionally, temperature.

SPNPVW iprof nmprofPRESSURE pres1 pres2 ... presk(TEMP temp1 temp2 ... tempmIPRES (ITEMP) DENS VISip1 (it1) dens1 vis1. ( . ) . .. ( . ) . .. ( . ) . .ipk (itm) denskm viskm

Definitions:

iprof Number of the water PVT profile table being read.

nmprof Water PVT profile name.

PRESSURE Alpha label indicating that pressure values are read on this card.


TEMP Alpha label indicating that temperature values are read on this card. This card is optional.

temp Temperature values, oF (oC). Values can be unequally spaced.

IPRES Alpha label indicating that the values read in the column under this heading are reservoir pressure indices.

ITEMP Alpha label indicating that the values read in the column under this heading are temperature indices. This label can be included only if a TEMP card was input.

DENS Alpha label indicating that the values read in the column under this heading are densities.

5000.4.4 10-543


Example:

SPNPVW 1 WPR1PRESSURE 14.7 8000TEMP 60 160IPRES ITEMP DENS VIS 1 1 1.02 1.17 2 1 1.05 1.14 1 2 1.00 0.42 2 2 1.02 0.45

10.15.2 Surface Network PVT Unit (SPNPVT)

The SPNPVT card is used to assign hydrocarbon and water PVT tables to PVT units.

SPNPVT mu un1 un2) ... unmu ipvt1 ipvt2) ... ipvtmu ipvtw1 ipvtw2) ... ipvtwmu

Definitions:

mu Total number of PVT units. If mu is zero, the SPN PVT Unit option will not be activated.

un List of PVT units.

ipvt Hydrocarbon PVT table numbers or PVT profile names assigned to the corresponding PVT units.

ipvtw Water PVT table numbers or water PVT profile names (Section 10.15.1) assigned to the corresponding PVT units.

VIS Alpha label indicating that the values read in the column under this heading are viscosities.

ipk Index refering to the k-th pressure value read.

itm Index refering to the m-th temperature value read. This index can be included only if a TEMP card was input.

denskm The density value corresponding to the indicated pressure (and temperature) value(s), gm/cc.

viskm The viscoity value corresponding to the indicated pressure (and temperature) value(s), cp.

10-544 5000.4.4


Example:

SPNPVT 51 2 3 4 5PRF1 PRF2 1 2 3WPR1 WPR1 WPR1 1 1

10.15.3 Well PVT Unit (SPNPTU)

The SPNPTU card is used to assign PVT unit numbers to wells.

SPNPTU wlun1 un2 . . . unn

Definitions:

wl List of wells for which PVT unit numbers are being entered (see Section 1.5.2).

pres PVT unit numbers.


FPERF WELL . . . . (SPNPTU) . . . .

. . . . (spnptu) . .

Definitions:

SPNPTU Column heading for spnptu, the SPN PVT unit for this well perforation. Default is the well’s PVT unit if the SPNPTU (Section 10.15.3) card for the well is specified. Otherwise, default is the gridblock’s equilibium region number.

5000.4.4 10-545


10.16 Pseudo Well Option

In some cases, sections of an oil/gas field are not represented in a reservoir model but wells located in these sections are connected to the surface pipeline network system. The pseudo well option has been implemented to represent production from wells (which are not included in the reservoir model) using well inflow correlations. The pseudo well option also can be used for satellite oil field modeling. In this case, each satellite oil field should be represented as a pseudo well.

The pseudo well option has been implemented only for production wells.

As a minimum, the following input are required for modeling each pseudo well:

• the WELL card to assign a gathering center and a separator battery,

• the PROD card to define the well type,

• the FPERF card. Default values of reservoir pressure and fluid composition in the pseudo well are computed as averaged values from the perforated gridblocks defined with this card. The PSEUPRES and PSEUXY cards can be used to overwrite the default values,

• the QMAX card to set the maximum production rate,

• three BHITAB tables to use in the well inflow performance correlations,

• the PSEUTAB card to assign the corresponding well inflow correlations (the BHITAB tables) to the pseudo well.

In addition, most well management options (for example, BHP, THP, QMIN, ITUBE, WELCON, etc) can be used for the pseudo wells.

The production from the pseudo well can be included in the reservoir material balance calculations using the PSEUWS card(s). Also, the PSEUWS card can be used to convert a pseudo well to a “normal” production well or a “normal” well to a “pseudo” well.

The following three well inflow correlations must be defined for each pseudo well:

1. Bottomhole pressure as a two-dimensional tabular function of resevoir pressure and production rate (oil, gas, water, or liquid).

2. Gas-oil ratio (or gas-liquid ratio, or oil-gas ratio) as a two-dimensional tabular function of resevoir pressure and production rate (oil, gas, water, or liquid).

3. Water cut (or water-gas ratio) as a two-dimensional tabular function of resevoir pressure and production rate (oil, gas, water, or liquid).

10-546 5000.4.4


Also, a special option has been provided to define tubinghead pressure as a tabular two-dimensional function of resevoir pressure and production rate (oil, gas, water, or liquid). For this option, a tubing string model must be assigned to the pseudo well in the WELCON card. The simulator internally calculates bottomhole pressure for each entry of the two-dimensional BHITAB table. Then, it determines parameters of Bendakhia and Aziz’s inflow performance relationships (see SPE Paper 19823: H. Bendakhia and K. Aziz “Inflow Performance Relationships for Solution-Gas Drive Horizontal Wells” presented in the 64th Annuak Technical Conference and Exhibition held in San Antonia, TX, October 8-11, 1989) using a curve fitting procedure.

10.16.1 Inflow Performance Correlations (BHITAB)

Three inflow performance correlations must be defined for each pseudo well: BHP/THP, GLR/GOR/OGR, and WCUT/WGR.

BHITAB nbhi

OGWL

QI q1 q2 ... qkQLIFT g1 g2 ... gkPRES p1 p2 ... pn

IPRES

BHP IQ

THP IQ GLR IQ GOR IQ OGR IQ WCUT IQ WGR IQ

ipres1 par(iq1) par(iq2) ... par(iqk).........ipresn par(iq1) par(iq2) ... par(iqk)

Definitions:

nbhi Number of the inflow performance table being read.

O Alpha label indicating that oil rates are entered on the QI line. This is the default.

5000.4.4 10-547


G Alpha label indicating that gas rates are entered on the QI line.

W Alpha label indicating that water rates are entered on the QI line.

L Alpha label indicating that liquid rates are entered on the QI line.

QI Alpha label indicating that values on this card are production rates.

q Production rates; oil, water and liquid, STB/D (STM3/D), or gas MSCF/D (SM3/D). Values can be unequally spaced and must increase monotonically.

QLIFT Alpha label indicating that values on this card are gaslift gas rates.

g Gaslift gas rates, MSCF/D (SM3/D). The number of values must equal the number of values on the QI card.

PRES Alpha label indicating that values on this card are reservoir pressure.

p Reservoir pressure values, psia (kPa). Values can be unequally spaced and must increase monotonically.

IPRES Alpha label indicating that the values read in the column under this heading are reservoir pressure indices.

BHP(IQ) Alpha label indicating that the values read in the column under this heading are bottomhole pressure values for each production rate input. Parentheses must appear in this alpha label.

THP(IQ) Alpha label indicating that the values read in the column under this heading are tubinghead pressure values for each production rate input. Parentheses must appear in this alpha label. The simulator internally calculates bottomhole pressure for each entry of the two-dimensional BHITAB table. Then, it determines parameters of Bendakhia and Aziz’s inflow performance relationships using a curve fitting procedure.

GLR(IQ) Alpha label indicating that the values read in the column under this heading are gas-liquid ratio values for each production rate input. Parentheses must appear in this alpha label.

10-548 5000.4.4


NOTE: 1. Liquid rate (L) must be used with gas-liquid ratios (GLR(IQ)). Oil rate (O) must be used with gas-oil ratios (GOR(IQ)).Gas rate (G) must be used with oil-gas ratios (OGR(IQ)). Liquid rate (L) or oil rate (O) must be used with water cuts (WCUT(IQ)). Gas rate (G) must be used with water-gas ratios (WGR(IQ)).

2. When tubinghead pressures (THP(IQ)) are input, the first rate entry q1 must be zero.

3. QLIFT data may only be entered when tubinghead pressures (THP(IQ)) are input.

4. Bottomhole pressures/tubinghead pressures may not exceed the maximum reservoir pressure pn.

5. A tubinghead pressure correlation may be assigned to only one pseudo well.

GOR(IQ) Alpha label indicating that the values read in the column under this heading are gas-oil ratio values for each production rate input. Parentheses must appear in this alpha label.

OGR(IQ) Alpha label indicating that the value read in the column under this heading are oil-gas ratio values for each production rate input. Parentheses must appear in this alpha label.

WCUT(IQ) Alpha label indicating that the values read in the column under this heading are water cut values for each production rate input. Parentheses must appear in this alpha label.

WGR(IQ) Alpha label indicating that the values read in the column under this heading are water-gas ratio values for each production rate input. Parentheses must appear in this alpha label.

ipresn Index refering to the n-th reservoir pressure entry read.

par(iq) Value of corresponding parameter, psia (kPa) if BHP or THP;SCF/STB (SM3/STM3) if GLR or GOR;STB/SCF (STM3/SM3) if OGR; fraction if WCUT;STB/SCF (STM3/SM3) if WGR;for corresponding production rate. The corresponding production rate is the q value that would correspond to iq. The number of parameter values on this card must equal to the number of q values on the QI card.

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Example:

C Inflow performance Curve for Well TB04BHITAB 26 OQI 140 280 420 560 700 840 980 1120 1260 1400PRES 4604IPRES BHP(IQ)1 4509 4410 4310 4211 4112 4012 3913 3813 3714 3614CC Gas-Oil Ratio Curve for Well TB04BHITAB 27 OQI 140 280 420 560 700 840 980 1120 1260 1400PRES 4604 IPRES GOR(IQ)1 1289 1330 1344 1350 1354 1356 1358 1360 1361 1362CC Water Cut Curve for Well TB04BHITAB 28 OQI 140 280 420 560 700 840 980 1120 1260 1400PRES 4604 IPRES WCUT(IQ)1 .598 .674 .693 .702 .707 .711 .713 .715 .716 .717

10.16.2 Correlation Assignments (PSEUTAB)

Assignments of inflow performance correlations (BHITAB tables) to each pseudo well are input using the PSEUTAB card.

PSEUTAB well ibhp ig iw

Definitions:

well Well name or well number of a pseudo well.

ibhp BHITAB table number which defines bottomhole pressure or tubinghead pressure as a tabular function of production rate and reservoir pressure (BHP(IQ) or THP(IQ)).

ig BHITAB table number which defines gas-liquid ratio, or gas-oil ratio, or oil-gas ratio as a tabular function of production rate and reservoir pressure (GLR(IQ), or GOR(IQ), or OGR(IQ)).

iw BHITAB table number which defines water cut or water-gas ratio as a tabular function of production rate and reservoir pressure (WCUT(IQ) or WGR(IQ)).

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Example:

PSEUTAB TB04 26 27 28

10.16.3 Reservoir Pressure (PSEUPRES)

Reservoir pressure used in inflow performance correlations for pseudo wells can be input using the PSEUPRES card.

PSEUPRES wlpres1 pres2 . . . presn

Definitions:

wl List of pseudo wells for which reservoir pressure values are being entered (see Section 1.5.2).

pres Reservoir pressure value, psia (kPa), used in inflow performance correlations for the corresponding pseudo well. If a value of –1 is entered as a reservoir pressure or the PSEUPRES card is not entered for a pseudo well, the average reservoir pressure in gridblocks with open well perforations is used.

Example:

PSEUPRES TB04 TB06 TB07 4604 4700 -1

10.16.4 Compositions (PSEUXY)

Compositions of liquid and vapor hydrocarbon phases for pseudo wells can be input using the PSEUXY card.

PSEUXY wlx1 x2 ... xk ... xncy1 y2 ... yk ... ync

Definitions:

wl List of pseudo wells for which compositions of liquid and vapor hydrocarbon phases are being entered (see Section 1.5.2).

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Example:

PSEUXY TB04 TB06 .8934337E-01 .4506625E+00 .5055475E-01 .3244427E-01 .5654376E-02 > .1570380E-01 .1594286E-01 .7097116E-01 .9432530E-01 .6633679E-01 > .6332303E-01 .4473776E-01 .1156343E+00 .7543256E+00 .5447269E-01 .2560875E-01 .3748278E-02 > .9230980E-02 .6947261E-02 .1682564E-01 .1040004E-01 .2378132E-02 > .4222647E-03 .6095310E-05PSEUXY TB07 -1 0 0 0 0 0 0 0 0 0 0 0 1 0 0 0 0 0 0 0 0 0 0 0

10.16.5 Well Status (PSEUWS)

The production from pseudo wells can be included in the reservoir material balance calculations using the PSEUWS card(s). Also, the PSEUWS card can be used to convert pseudo wells to “normal” production wells or “normal” production wells to “pseudo” wells.

PSEUWSTABLE

NORMAL

IGNOREINCLUDE

wl

Definitions:

xk Molar fraction of the k-th hydrocarbon component in the liquid phase of fluids produced in the corresponding pseudo wells, fraction. If a value of -1 is entered as the first component fraction or the PSEUXY card is not entered for a pseudo well, the average values of the compositions in gridblocks with open well perforations are used.

yk Molar fraction of the k-th hydrocarbon component in the vapor phase of fluids produced in the corresponding pseudo well, fraction.

wl List of pseudo wells for which data is being entered (see Section 1.5.2).

TABLE Alpha label indicating that the wells in the specified list are to be considered as “pseudo” wells.

NORMAL Alpha label indicating that the pseudo wells in the specified list are to be considered as “normal” production wells.

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NOTE: If the PSEUTAB cards are used for some production wells these wells are considered as pseudo wells and inflow performance correlations are applied from production modeling in these wells. In some time during the simulation, you can switch these wells to “normal” wells using the PSEUWS card(s). Later you can convert them back to the pseudo wells (again applying the PSEUWS cards) if it is required.The IGNORE option can be applied only for pseudo wells.

Example:

PSEUWS NORMAL TB04 TB05PSEUWS TABLE INCLUDE TB07

IGNORE Alpha label indicating that production from the pseudo wells in the specified list is to be excluded from reservoir material balance calculations. This option is not compatible with NORMAL.

INCLUDE Alpha label indicating that production from the wells in the specified list is to be included in reservoir material balance calculations.

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10.17 General Parameters of the Surface Pipeline Network System (NETPAR)

General parameters of the surface pipeline network system can be divided into the following groups:

• default parameters of pressure calculations in pipes and well tubing strings (YOUNG, PRESIN),

• parameters and tolerances which are used in the phase-equilibrium calculations (TOLRKV, TOLRTC, TOLRPC, TOLRSP, TOLCP, TOLCMC, MAXFLI, MAXSSI),

• parameters and tolerances that are applied for the determination of the pressure distribution in the surface pipeline network system (PS, TS, TNET, MAXNIT, PRRTOL, RTRTOL, TIMEIN, TIMEST, OUTITR, GASLIF, OUTFIL, FRLOSS),

• parameters of the simplified heat transfer analysis option for production networks only (HEATTR, SHCOIL, SHCGAS, SHCWAR, HTCPIPE, HTCTUB),

• pressure gradient correction factors (GRPGCR, FRPGCR, ACPGCR), and

• parameters used for sonic velocity calculations (SVLOIL, SVLGAS, SVLWAT).

NETPAR param1 param2 . . . paramnvalue1 value2 . . . valuen

Definitions:

param Alpha labels of those node parameters being defined. The following parameters can be input:

YOUNG, PRESIN,

TOLRKV, TOLRTC, TOLRPC, TOLRSP, TOLCP, TOLCMC, MAXFLI, MAXSSI,

PS, TS, TNET, MAXNIT, PRRTOL, RTRTOL, TIMEIN, TIMEST, OUTITR, GASLIF, OUTFIL, FRLOSS,

HEATTR, SHCOIL, SHCGAS, SHCWAT, HTCPIPE, HTCTUB,

GRPGCR, FRPGCR, ACPGCR,

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SVLOIL, SVLGAS, SVLWAT

PIPE AND TUBING DEFAULT PARAMETERS

YOUNG Default value of the Young modules (see descriptions of the YOUNG keyword in the PIPES and TUBING cards), million psia (million kPa). Default is 30.E+6 psia.

PRESIN Default value of the pressure increment (see descriptions of the PRESIN keyword in the PIPES and TUBING cards), psia (kPa). Default is 400 psia.

PARAMETERS OF FLASH CALCULATIONS

MAXFLI Maximum number of iterations allowed for phase-equilibrium calculations. Default is 20.

MAXSSI Maximum number of successive-substitution iterations allowed for phase-equilibrium calculations. The successive-substitution procedure is used as the preconditioning step in the phase-equilibrium calculations. Default is 4.

TOLRKV Relative K-value tolerance. It is assumed that the phase equilibrium calculations converge in an iteration when the maximum value of relative K-value changes is less than the tolerance TOLRKV and a matrix of second derivatives of the Gibbs free energy function is positive-definite. Default is .005.

TOLCP Chemical potential tolerance. It is assumed that the phase equilibrium calculations converge in an iteration when the maximum value of absolute differences between chemical potentials in liquid and vapor hydrocarbon phases is less than the tolerance TOLCP and a matrix of second derivatives of the Gibbs free energy function is positive-definite. Default is .0001.

TOLRTC Relative temperature tolerance. The phase equilibrium computations are not repeated if relative changes of temperature, pressure, and composition are less than the corresponding tolerances TOLRTC, TOLRPC, and TOLCMC, and if the relative difference between the current pressure and the previously calculated saturation pressure is larger than TOLRSP. Default is .01.

5000.4.4 10-555


TOLRPC Relative pressure tolerance. The phase equilibrium computations are not repeated if relative changes of pressure, temperature, and composition are less than the corresponding tolerances TOLRPC, TOLRTC, and TOLCMC, and if the relative difference between the current pressure and the previously calculated saturation pressure is larger than TOLRSP. Default is .001.

TOLCMC Composition tolerance. The phase equilibrium computations are not repeated if the maximum value of composition changes and relative changes of pressure, and temperature are less than the corresponding tolerances TOLCMC, TOLRPC, and TOLRTC, and if the relative difference between a current pressure and the previously calculated saturation pressure is larger than TOLRSP. Default is .001.

TOLRSP Saturation pressure tolerance. The phase equilibrium computations are not repeated if the relative difference between the current pressure and the previously calculated saturation pressure is larger than TOLRSP, and if relative changes of pressure, temperature, and composition are less than the corresponding tolerances TOLRPC, TOLRTC, and TOLCMC. Default is .001.

PARAMETERS OF SURFACE PIPELINE NETWORK CALCULATIONS

TS Standard temperature, °F (°C). Default is 60°F (15°C).

PS Standard pressure, psia (kPa). Default is 14.65 psia (101.325 kPa or 1.03353 kg/cm2).

TNET Default value of temperature in nodes of the surface pipeline network system, °F (°C). Default is 60°F (15°C).

TIMEIN Time increment between two sequential recalculations of production rates using the surface pipeline network option, days. Default is 99999 days.

TIMEST Maximum number of timesteps between two sequential recalculations of production rates using the surface pipeline network option. Default is 1.

OUTITR Maximum number of outer iterations in which the surface pipeline network calculations are executed. Default is 2.

MAXNIT Maximum number of iterations allowed in the surface pipeline network calculations. Default is 100.

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PRRTOL Relative pressure tolerance. It is assumed that the surface pipeline network calculations converge if the relative difference between bottomhole pressure values on the inflow performance curve (defined by a wellbore model) and outflow performance curve (defined by the surface pipeline network model) is less than the tolerance PRRTOL in any production well connected to the surface pipeline network system. Default is .0001.

RTRTOL Relative rate tolerance. It is assumed that the surface pipeline network calculations converge if the relative difference between values of the specified rate and the calculated rate in a node of the surface pipeline network system is less than the tolerance RTRTOL. Default is .001.

GASLIF Gaslift indicator. Gaslift rates are included in the surface pipeline network calculations if the value of this parameter is one. They are excluded from these calculations only if a value of zero is input. Default is one.

OUTFIL Fortran unit number used for the output of the tubing report. Default is 30.

FRLOSS Friction loss indicator. The friction loss between perforations of a horizontal or inclined well will be computed if the value of this parameter is one. It will be ignored if the value is zero. Default is zero.

PARAMETERS OF HEAT TRANSFER ANALYSIS (Applies only to production networks.)

HEATTR Heat transfer analysis indicator. This parameter must be set to one to apply the simplified heat transfer analysis option for the determination of the temperature distribution in the network. The option is not used if the parameter value of zero is input. Default is zero.

SHCOIL Specific heat capacity of oil, BTU/(lbm*oF) (J/(kg*oK). This parameter is applied only if the simplified heat transfer analysis option is used. Default is 0.53 BTU/(lbm*oF).

SHCGAS Specific heat capacity of gas, BTU/(lbm*oF) (J/(kg*oK). This parameter is applied only if the simplified heat transfer analysis option is used. Default is 0.51 BTU/(lbm*oF).

5000.4.4 10-557


NOTE: In-situ fluid velocity in pipes and tubing strings is limited by the fluid sonic velocity. The sonic velocity of the multiphase fluid which depends on properties of oil, gas, and water is calculated using Gould’s method. If the in-situ fluid velocity in pipes and tubing strings exceeds 95% of the fluid sonic velocity, it is reduced to this value.

Examples:

CC General parameter input.CNETPARPS TS MAXNIT PRRTOL TIMEIN14.7 60. 30 1.E-4 15

SHCWAT Specific heat capacity of water, BTU/(lbm*oF) (J/(kg*oK). This parameter is applied only if the simplified heat transfer analysis option is used. Default is 1.0 BTU/(lbm*oF).

HTCPIPE Default value of heat transfer coefficient of pipes, BTU/hr*ft2*oF), (W/(m2*oK). This parameter is applied only if the simplified heat transfer analysis option is used. Default is 1.0 BTU/(hr*ft2*oF).

HTCTUB Default value of heat transfer coefficient of tubing, BTU/(hr*ft2*oF), (W/(m2*oK). This parameter is applied only if the simplified heat transfer analysis option is used. Default is 3.0 BTU/(hr*ft2*oF).

GRPGCR Correction factor for gravity pressure gradient in pipes and tubing, fraction. Default is 1.0.

FRPGCR Correction factor for friction pressure gradient in pipes and tubing, fraction. Default is 1.0.

ACPGCR Correction factor for acceleration pressure gradient in pipes and tubing, fraction. Default is 0.0.

SVLOIL Sonic velocity of oil, ft/s (m/s). Default is 3000 ft/s.

SVLGAS Sonic velocity of gas, ft/s (m/s). Default is 1200 ft/s.

SVLWAT Sonic velocity of water, ft/s (m/s). The default value is 2700 ft/s.

value Value of the corresponding parameter.

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10.18 Output of Surface Pipeline Network Information

Results of the well tubing string and surface pipeline network calculations can be output in the following reports:

• node report,

• node spreadsheet.

• tubing report, and

• automatic tuning reports (see Chapter 11).

They also can be output in the plot file.

Five-dimensional hydraulic tables can be generated for any well tubing string and/or any connection between nodes of the surface pipeline network system at any time during the simulation.

10.18.1 Node Report in Print File

Pressures and rates at different nodes of the surface pipeline network system can be output in the print file using the modified WLGRP card with the keyword NODES. The information will be printed for nodes specified after the WLGRP card. Also, a well report will be output for all production or injection wells connected to the specified nodes through the surface pipeline system. The frequency of the node and group report output can be controlled by the PRINT WLGRP card.

WLGRP grpnum (grpnam) NODESnode_list

Definitions:



NODES Alpha label indicating that node report will be generated.

node_list List of surface pipeline network nodes belonging to the group. A value of NN or a NAME parameter from the NODES card can be input in this list.

5000.4.4 10-559


Examples:

WLGRP 1 WELLGR1 NODESNODE1 2 4

WLGRP 2 NODES5

10.18.2 Node Spreadsheet File (SSSUM)

The SSSUM card, with the NODE keyword, is used to specify options and variables to appear in the node spreadsheet summary file. See section 6.18 for a description of the other types of spreadsheet files that may be requested. The node spreadsheet file is written to FORTRAN Unit 80. The frequency of the output is controlled by the SSSUM parameter on the PRINT card.

No variables are automatically written to this file. Each must be explicitly requested.

SSSUM NODE (TAB) (HEADER) varnm1 varnm2 ... varnmn

Definitions:

NODE Alpha label indicating that the subsequent data applies to the node spreadsheet file.

TAB Alpha label indicating that the columns will be separated by a tab character. Omission will result in columns separated by a comma.

HEADER Alpha label indicating that a title line, column header line, and a units line should be included in the file at each time.

varnm Alpha label specifying one or more of the following variables:

NUMBER Node number.

NAME Node name.

TIME Simulation time.

DATE Calendar date.

TSNUM Timestep number.

QGP Gas production rate.

QOP Oil production rate.

10-560 5000.4.4


QWP Water production rate.

CGP Cumulative gas production.

COP Cumulative oil production.

CWP Cumulative water production.

QGI Gas injection rate.

QWI Water injection rate.

CGI Cumulative gas injection.

CWI Cumulative water injection.

TEMP Node temperature.

PRES Node pressure.

WMLVL Associated well management level.

WMNAME Well management member name.

WMNUM Well management member number.

NOTE: 1. All of the alpha labels must appear on one SSSUM card. If necessary, the continuation character ‘>‘ can be used.

2. The alpha label NODE must be specified to obtain the node spreadsheet file.

3. Except for TAB and HEADER, the order of the alpha labels is the order the variables will appear in the file.

4. Each SSSUM NODE card supercedes and replaces the previous SSSUM NODE card.

5000.4.4 10-561


10.18.3 Spreadsheet Node Specification (SPRLIST)

The SPRLIST card is used to specify which nodes are to be included in the node spreadsheet file.

SPRLIST NODE ON

OFF ALL

nodelist

Definitions:

NODE Alpha label indicating that the data on this card applies to the node spreadsheet file.

ON Alpha label indicating that the specified nodes are to be included in the spreadsheet file.

OFF Alpha label indicating that the specified nodes are to be excluded from the spreadsheet file.

ALL Alpha label indicating that the data on this card applies to all nodes.

nodelist List of nodes to which the data on this card applies.

NOTE: 1. If the SPRLIST card is not entered, all nodes are included in the spreadsheet file.

2. To restrict the nodes on the spreadsheet file, all nodes must first be excluded (OFF), then the desired nodes included (ON).

10-562 5000.4.4


10.18.4 Tubing Report

A tubing report can be output for any set of wells at any time during simulation. Pressure, temperature, hold-up, flow regime, pressure gradient, in situ velocities, and densities at different subsea depths of well tubing strings are included in the report. Values of these variables are printed at the subsea depths defined in the CURVE ELEVPR card. If the CURVE ELEVPR card is not used for some tubing segment, the values of the specified variables are printed in the inlet and outlet of the tubing segment. The tubing report is generated in Fortran unit OUTFIL, which can be input in the NETPAR card. The default unit number is 30.

The following steps are required to print the tubing report:

1. Group all wells for which the tubing reports must be generated in some well group using the WLGRP card;

2. Include the TUBING keyword in the WLGRP card;

3. Determine frequencies of the tubing report output in the PRINT WLGRP card.

WLGRP grpnum (grpnam) TUBINGwell_list

Definitions:



TUBING Alpha label indicating that tubing report will be output.

well_list List of wells for which the tubing report will be generated.

Examples:

WLGRP 3 WELLGR3 TUBINGWELL1 WELL2

PRINT WLGRP TIME

5000.4.4 10-563


10.18.5 Surface Pipeline Network Information in Plot File

Pressure and rates at different nodes of the surface pipeline network system will be output in the plot records if the keyword PLOT is included in the Utility Data, the keyword WPLOT is included in the recurrent data, and:

1. when the vdb file is being written, the SURFACE class of data is requested on the PLOT card,

2. when the plot file is being written, the GATHER class of data is requested on the PLOT card.

10.18.6 Generation of Hydraulic Tables (HTOUTPUT)

Five-dimensional hydraulic tables can be generated for any well tubing string and/or any connection between nodes of the surface pipeline network system at any time during the simulation. The hydraulic table constructs pressure at the inlet of the connection (well tubing string or connection between nodes) as a five-dimensional tabular function of pressure at the outlet of the connection, liquid rate, gas-oil ratio, water cut, and gas-lift rate. Alternatively, oil or gas rate may be used instead of the liquid rate, oil-gas ratio may be used instead of the gas-oil ratio, and water-gas ratio may be used instead of the water cut.

If the HTOUTPUT is requested for some well, the hydraulic table will be generated for the tubing string of this well. If the HTOUTPUT is requested for some node, the hydraulic table will be generated for the output connection between this node and the node of the higher level.

Liquid or gas hydraulic tables can be generated. For the generation of the liquid hydraulic table, outlet pressure entries (PRESSURE card), liquid or oil rate entries (QLIQ or QO card), gas-oil ratio entries (GOR card), and water cut entries (WCUT card) must be input. Optionally, the gas-lift rate entries (GASLIFT card) may also be input. For the generation of a gas hydraulic table, outlet pressure entries (PRESSURE card), gas rate entries (QGAS card), oil-gas ratio entries (OGR card), and water-gas entries (WGR card) must be input.

The hydraulic table is generated at the end of the timestep following the specification of the HTOUTPUT card.

Hydraulic tables can be generated only for wells (and/or nodes) with non-zero production rates at the end of the timestep following the specification of the HTOUTPUT card. Also, the well tubing strings (node connections) for which the output of the hydraulic tables are requested must be assigned to the wells (nodes) in the WELCON (NODCON) cards. The corresponding WELCON (NODCON) cards must be input before the HTOUTPUT card.

10-564 5000.4.4


The generated hydraulic tables can be output in BHPTAB format or they can be output in spreadsheet format. If the BHPTAB format is applied, the hydraulic table can be used as input data in a VIP-EXEC data set.

The generated hydraulic tables are stored internally in VIP, and they can be used in LINK cards. However, they can be referenced in the LINK cards only after the DATE/TIME card following the HTOUTPUT input.

If the hydraulic table is generated for a well tubing string, the THP values in the table are the values of tubinghead pressure at the subsea depth of the wellhead which is input as WELHEAD in the corresponding WELCON card. The BHP values in the table are the values of bottomhole pressure at the reference depth. The reference depth is defined as the subsea depth of the first active perforation if it is smaller than the subsea depth of the tubing string bottom. Otherwise, the reference depth is determined as the subsea depth of the tubing string bottom. The subsea depth of the first active perforation can be input by the user in the WELCON card as the WDZ parameter. If it is not input, the subsea depth of the first active perforation is determined by the simulator as the subsea depth of the top of the first open perforation with non-zero permeability-thickness. The difference between the reference depth and the wellhead subsea depth is printed as the third parameter in the BHPTAB card.

If the hydraulic table is generated for a node, the THP values in the table are the values of pressure at the outlet of the connection between this node and the node of the higher level. The BHP values in the table are the values of pressure at the inlet of the connection. The difference between the subsea depth of the connection inlet and the subsea depth of the connection outlet is printed as the third parameter in the BHPTAB card.

Values of oil and gas rates required for the construction of the hydraulic table are determined using the separator battery assigned to the corresponding well (node) in the WELL (NODES) card as the IBAT parameter.

The number of the gas-oil ratio (oil-gas) entries must be input in the GOR (OGR) card. Values of the gas-oil ratio entries are calculated internally by varying the liquid mole fraction in the range from 0.05 to 0.95, or the range specified by the user, with equally spaced intervals.

Number of entries, minimum value, and maximum value must be input in each of the PRESSURE, QLIQ/QO/QGAS, WCUT/WGR, and GASLIFT cards. Values of each of the entries will be equally spaced.

5000.4.4 10-565


HTOUTPUT

WELLS w1tnw1 tnw2 tnwn

NODES n1tnn1 tnn2 tnnn

PRESSURE nnp pmin pmax

QLIQQO

QGAS

nnq qmin qmax

GOROGR

nng gmin gmax

WCUTWGR

nnw wmin wmax

(GASLIFT nngl glmin glmax)

(FILENUMBER un (SPREADSHEET))

Definitions:

WELLS Alpha label indicating that the well list is input in this card.

wl List of wells for which hydraulic tables should be generated. (See Section 1.5.2)

tnw Hydraulic table numbercorresponding to each well. The table number should not exceed NBHPMX defined in the DIM card.

NODES Alpha label indicating that the node list is input in this card.

nl List of nodes for which hydraulic tables should be generated. (See Section 1.5.2)

tnn Hydraulic table number corresponding to each node. The table number should not exceed the NBHPMX limit defined in the DIM card.

PRESSURE Alpha label indicating that the outlet pressure entries in the hydraulic tables are described in this card.

10-566 5000.4.4


nnp Number of outlet pressure entries (THP) in the hydraulic tables. The number of outlet pressure entries should not exceed the NBHPQ limit defined in the DIM card.

pmin Minimum value of the outlet pressure entries (THP) in the hydraulic tables, psia (kPa).

pmax Maximum value of the outlet pressure entries (THP) in the hydraulic tables, psia (kPa).

QLIQ Alpha label indicating that the liquid rate entries in the hydraulic tables are described in this card. This must be used with PRESSURE, GOR, and WCUT.

QO Alpha label indicating that the oil rate entries in the hydraulic tables are described in this card. This must be used with PRESSURE, GOR, and WCUT.

QGAS Alpha label indicating that the gas rate entries in the hydraulic tables are described in this card. This must be used with PRESSURE, OGR, and WGR.

nnq Number of liquid, oil, or gas rate entries in the hydraulic tables. The number of the rate entries should not exceed the NBHPQ limit defined in the DIM card.

qmin Minimum value of the liquid or oil rate entries, STB/D (STM3/D), or the gas rate entries, MSCF/D (SM3/D) in the hydraulic tables.

qmax Maximum value of the liquid or oil rate entries, STB/D (STM3/D), or the gas rate entries, MSCF/D (SM3/D) in the hydraulic tables.

GOR Alpha label indicating that the gas-oil ratio entries in the hydraulic tables are described in this card. This must be used with QLIQ and QO.

OGR Alpha label indicating that the oil-gas ratio entries in the hydraulic tables are described in this card. This must be used with QGAS.

nng Number of gas-oil ratio or oil-gas ratio entries in the hydraulic tables. The number of gas-oil ratio or oil-gas ratio entries should not exceed the NBHPQ limit defined in the DIM card.

gmin Minimum value of the liquid mole fraction, to be used in computing gas-oil ratio or oil-gas ratio. Default is 0.05.

5000.4.4 10-567


NOTE: 1. The number of tnw values must equal the number of wells in the well list.

gmax Maximum value of the liquid mole fraction, to be used in computing gas-oil ratio or oil-gas ratio. Default is 0.95.

WCUT Alpha label indicating that the water cut entries in the hydraulic tables are described in this card. This must be used with QLIQ and QO.

WGR Alpha label indicating that the water-gas ratio entries in the hydraulic tables are described in this card. This must be used with QGAS.

nnw Number of water cut or water-gas ratio entries in the hydraulic tables. The number of water cut or water-gas ratio entries should not exceed the NBHPQ limit defined in the DIM card.

wmin Minimum value of the water cut entries, fraction, or water-gas ratio entries, STB/MMSCF (STM3/KSM3) in the hydraulic tables.

wmax Maximum value of the water cut entries, fraction, or water-gas ratio entries, STB/MMSCF (STM3/KSM3) in the hydraulic tables.

GASLIFT Alpha label indicating that the gas-lift rate entries in the hydraulic tables are described in this card. This can be used with QLIQ or QO.

nngl Number of gas-lift rate entries in the hydraulic tables. The number of gas-lift rate entries should not exceed the NBHPQ limit defined in the DIM card.

glmin Minimum value of the gas-lift rate entries in the hydraulic tables, MSCF/D (SM3/D).

glmax Maximum value of the gas-lift rate entries in the hydraulic tables, MSCF/D (SM3/D).

FILENUMBER Alpha label indicating that the FORTRAN logical unit for the output of the hydraulic tables is input in this card.

un FORTRAN logical unit for the output of the hydraulic tables. Default is 6.

SPREADSHEET Alpha label indicating that the hydraulic tables must be output in spreadsheet format. If the SPREADSHEET keyword is not input, the hydraulic tables are output in BHPTAB format.

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2. The number of tnn values must equal the number of nodes in the node list.

3. The total number of inlet pressure values (BHP), which is equal to nnp * nng * nnw * nng1, should not exceed the NBHPV limit defined in the DIM card.

4. One and only one of the QLIQ, QO, or QGAS labels must be specified.

5. One and only one of the GOR or OGR labels must be specified.

6. One and only one of the WCUT or WGR labels must be specified.

Example:

CC Apply Link LINK1 for tubing string modeling in Well WELL1 C LINK 1 LINK1C NN Name Type Num Pressure_CorrectionIPVT 1 TUBIN1 TUBING 1 0. 2 2 TUBIN2 TUBING 1 10 1 3 TUBIN3 TUBING 1 15 3 WELCONWELL TUBCON TUBCNT WDZ WDATWELL1 LINK1 LINK 20500 21000CC Generate hydraulic table with Number 5 for Well WELL1CHTOUTPUTWELLS WELL1 5PRESSURE 11 1000 2000QLIQ 11 1000 40000GOR 4WCUT 6 0 0.95GASLIFT 2 0 6000FILENUMBER 30 SPREADSHEET..CC Apply the generated hydraulic table in Link LINK1 after DATE card following C the HTOUTPUT input.CDATE 1 12 2002C..

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LINK 1 LINK1C NN Name Type Num Pressure_Correction Separator 1 5 BHPTAB 1 0. IBAT 1

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10.19 Production Well Optimization Option

The production well optimization option allocates well production rates and selects the surface network connections through the maximization of the following objective function:

Objective Function = cojqoj cgjqgj cgjqglgj cwjqwj+ + +

j p1=

pn

where:

• qo, qg, qglg, and qw are the oil production, gas production, gaslift gas injection, and water production rates, respectively, and

• the objective coefficients, coj, cgj, and cwj, are specified by the user.

The well rates are constrained by maximum oil rate, total gas (production gas and gaslift gas) rate, liquid rate and well velocity specified at the well level. They are also constrained by maximum rates and velocity at the nodes. By assuming constant gas-oil ratio, water cut and total gas-liquid ratio, the problem is simplified to a linear optimization problem. The SLATEC (Sandia, Los Alamos, Air Force Weapons Laboratory Technical Exchange Committee) library, linear programming package dsplp is incorporated into VIP to solve this linear optimization problem.

10.19.1 Default Dimensions (DIM)


Definition:

MXLSPN Maximum number of levels for the surface pipeline network structure. Default is 5.

10.19.2 Objective Coefficients (OBJCOEF)

The OBJCOEF card is used to assign objective coefficients for wells. This card is required to turn on the production well optimization option.

OBJCOEF wlheadingsvalues

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Definitions:

wl List of wells for which objective coefficients are being specified (see Section 1.5.2). If the well list is not input, the coefficients are assumed to apply to all production wells.

OIL Column heading for Co, the objective coefficient for oil rate, (STB/D)-1, ((STM3/D)-1). Default is zero.

GAS Column heading for Cg, the objective coefficient for gas rate, (MSCF/D)-1, ((SM3/D)-1). Default is zero.

WATER Column heading for Cw, the objective coefficient for water rate, (STB/D)-1, ((STM3/D)-1). Default is zero.

NOTE: 1. For the optimization option to be performed, at least one well with non-zero objective coefficient must be specified.

2. All 3 headings do not have to be specified for a well, but the omitted coefficients are set to zero. That is, previously specified coefficients are not retained.

Examples:

CC DEFINE OBJECTIVE COEFFICIENTS FOR ALL C PRODUCTION WELLSCOBJCOEFOIL GAS WATER1. 0. 0.

10.19.3 Lock Well Rates (LOCK)

LOCK wl

ONOFF

Definitions:

wl List of wells for which lock status is being specified (see Section 1.5.2). If the well list is not input, the lock status is assumed to apply to all production wells.

ON This list of wells will be locked from production well optimization.

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OFF This list of wells will not be locked from production well optimization. This is the default.

Example:

CC LOCK WELL W32 AND E12A FROM PRODUCTION WELLC OPTIMIZATIONCLOCK W32 E12A

ON

10.19.4 Surface Network Optimization Control (NTOPTC)

The NTOPTC card is used to control the well and node reconnections in the production well optimization option. This card is required each time when the well and node reconnections are considered.

NTOPTC param1 param2 . . . paramn value2 value2 . . . valuen

Definitions:

param Alpha label of those control parameters being defined. The following parameters can be input:

DOBJMN Minimum increment of the objective function for a well to change its connection to another node. Default is zero. A value of zero means that the reconnection of wells to other nodes is not allowed. Default is 0.

NWSWT Maximum number of reconnections allowed for wells. Default is 0.

SIMPL Indicates whether the simplified method for the well rates calculation will be applied. The simplified method calculates well rates according to the new tubinghead pressure and it assumes that other well rates are not affected by the reconnection. YES means to use the simplified method; NO means not to use it. Default is NO.

NCYCLES Maximum number of search cycles performed in well connection optimization. One search cycle is defined as the procedure that all eligible wells have been tested for other potential reconnections. This parameter does not apply to node connection optimization. Default is 1.

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DOBJND Minimum increment of the objective function for a node to change its connection to another node. A value of zero means that the reconnection of wells to other nodes is not allowed. Default is 0.

NWSWT Maximum number of reconnections allowed for nodes. Default is 0.

VELRST Indicates whether velocity limits are to be reset if the specified velocity limits are violated. YES means to reset; NO means not to reset. Default is NO.

NOTE: When this card is entered, all data is reset to default values.

Example:

CC MAXIMUM 10 WELL RECONNECTIONS ARE ALLOWED.C EACH RECONNECTION NEEDS TO AT LEAST INCREASE C THE OBJECTIVE FUNCTION BY 100. MAXIMUM 2 SEARCH C CYCLES ARE ALLOWED.CNTOPTCDOBJMN NWSWT SIMPL NCYCLES100. 10 YES 2

10.19.5 Node Data (NODES)

NODES NN param1 param2 . . . paramn num1 value2 value2 . . . valuen

Definitions:

NN Alpha label indicating that the node number is input in this column.

num Node number. The node number must be input in increasing order.

param Alpha labels of those node parameters being defined. The following parameters are used for the well optimization option: QO, QG, QOMIN, QGMIN, PMAX, MAXVEL, VELWCU. PMAX, MAXVEL, VELWCU are new parameters.

PMAX Maximum pressure at the node for the changes of the node connection to be considered, psia (kPa). This

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parameter can be input only when the optimization option is used. If the node pressure is larger than the maximum pressure and several potential node connections are defined in the NODCON card, node reconnection will be considered. Default is –1.E15. If the user wants to turn off node reconnection, this parameter needs to be set to a large value.

MAXVEL Maximum velocity at the node if the water cut is greater than the value specified by the VELWCU parameter, ft/sec (m/sec).

VELWCU Minimum water cut for the maximum velocity constraint for the node to be activated, fraction.

10.19.6 Well Connection Data (WELCON)

WELCON WELL param1 param2 . . . paramn wn1 value2 value2 . . . valuen

Definitions:

WELL Alpha label indicating that this column will contain a name or number of a production well.

wn Name or number of a production well. A value of the N or NAME parameter from the WELL card should be used in this column.

param Alpha labels of those well parameters being defined. The following parameters are added for the well optimization option: QOMIN, QGMIN, PMAX.

QOMIN Minimum oil rate at the well, STB/D(STM3/D). This parameter is applied only if the optimization option is used. If the oil rate is less than the minimum value and several potential well connections are defined, well reconnection will be considered. Default is –1.E9.

QGMIN Minimum gas rate at the well, MSCF/D(SM3/D). This parameter is applied only if the optimization option is used. If the gas rate is less than the minimum value and several potential well connections are defined, well reconnection will be considered. Default is –1.E9.

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PMAX Maximum pressure for the changes of the well connection to be considered, psia(kPa). This parameter is applied only if the optimization option is used. If the well pressure is larger than the maximum pressure and several potential well connections are defined, well reconnection will be considered. Default is –1.E15. If the user wants to turn off well reconnection, this parameter needs to be set to a large value.

10.19.7 Maximum Velocity Constraints (WLVEL)

WLVEL (wl)MAXVEL (VELWCUT)mxvel (wcut)

Definitions:

wl List of wells for which maximum well velocity data is being specified (see Section 1.5.2). If the well list is not input, the data is assumed to apply to all production wells.

MAXVEL Alpha label indicating that the maximum velocity for a well connection will be entered.

VELWCUT Alpha label indicating that the minimum water cut for a velocity constraint to be activated will be entered.

mxvel Maximum velocity for a well connection, ft/sec (m/sec).

wcut Minimum water cut for the velocity constraint specified by MAXVEL to be activated, fraction. Default is 1.

10.19.8 Output Well and Node Connection Changes (PRTSWT)

The PRTSWT card is used to print surface network connection changes to the FORTRAN file named <casename>.conn_chg.

PRTSWT ONOFF

Definitions:

ON Well and node connection changes will be printed.

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OFF Well and node connection changes will not be printed. This is the default.

10.19.9 Gaslift Optimization Using Performance Curves (PFMCRV)

When the production well optimization option has been specified and gaslift performance curve data (PFMCRV, Section 4.10.10) has been entered, a separable programming (SP) gaslift optimization algorithm (SPE 29124, Fang and Lo, 1995) is used to calculate gaslift rates for the wells.

The SP procedure has three major steps:

1. Construct a gaslift performance curve (oil rate versus lift gas rate) for every well on automatic gaslift allocation:

a. Start with zero gaslift rate for the well.

b. Calculate the corresponding oil rate and gas-liquid ratio for that well.

c. If the gas-liquid ratio is smaller than the user-specified minimum gas-liquid ratio (glrmin or wglr in PFMCRV data), ignore this point (do not add this point onto the gaslift performance curve). Increase the lift gas rate and go to Step b. If the gas-liquid ratio is larger than the user-specified maximum gas-liquid ratio (glrmax in PFMCRV data), stop.

d. If the gaslift rate is nonzero, calculate the slope of the gaslift performance curve.

e. If the slope of the gaslift performance curve is positive, increase the gaslift rate and go to Step b. If the gaslift rate is negative, go to Step f.

f. Check the slope of the gaslift performance curve starting from the last point and ending at the first point. Cut the gaslift performance curve at the point where the slope of the curve is less than or equal to the user-specified minimum gaslift efficiency coefficient (eff in PFMCRV data).

2. Formulate the gaslift optimization problem as a linear programming problem using the gaslift performance curves constructed in Step 1. Solve the optimization problem and obtain the optimal gaslift rate qlg1 for each well. Denote the optimal objective function value (oil rate) as f.

3. Formulate a new optimization problem to minimize the absolute discrepancy between the pre-optimization gaslift rate, denoted as qlg0 and the optimal gaslift rate qlg1 by allowing the optimal oil rate obtained in Step 2 to decrease from f to (1-a) f, where a is called a relaxation factor or a damping factor (gldamp in PFMCRV data). The purpose of this step is to minimize the gaslift rate oscillations. This step is optional.

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10.20 Integration of Surface Pipeline Network and Predictive Well Management

The predictive well management option (PREDICT NEW) has been integrated with the surface pipeline network option. The integrated tools can be effectively used for well assignments to different pressure systems and well rate optimization. The predictive well management option is applied for the well allocations to the pressure systems. The surface pipeline network option is used for tubing head pressure and well rate calculations from pressure drop relationships in reservoir, tubing string, and flow lines. Well connections to nodes are automatically modified after well allocation to the pressure system.

The following input is required to combine two options:

1. Define all headers to which production wells can be connected as nodes of the surface pipeline network system. Assign well management level and pressure system for header nodes using keywords WML, WMN, PRSYS in the NODES card.

2. Determine current and potential well connections to headers using the keywords OUTNOD, OUTND2, OUTND3, OUTND4, OUTND5, and OUTND6 in the WELCON card. The OUTNOD keyword must be used for the current connection. The keywords OUTND2, OUTND3, OUTND4, OUTND5, and OUTND6 are used for potential connections.

10.20.1 Number of Outer Iterations Each Timestep (WMITN)

The WMITN card must be entered to use predictive well management.

WMITN nitn (nspnc)

Definition:

nitn Number of outer iterations in each timestep that will use predictive well management. Default is 0.

nspnc Frequency of the surface pipeline network calculations. Default is 1.

The WMITN card and the PREDICT card supply the enabling data for predictive well management. Both are necessary to use this option.

The WMITN card defines the number of outer iterations in each timestep that will use the predictive well management set of routines to calculate well rates and bottomhole pressures.

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It is recommended that the number of iterations be held to a small value, say 1 or 2. Larger values will probably degrade convergence considerably.

If the surface pipeline network option is used in combination with predictive well management, the surface pipeline network procedure is executed each nspnc-th execution of the predictive well management procedure. In this case, tubinghead pressure in production wells for each pressure system are recalculated only when the surface pipeline network procedure is executed. The TIMEIN, TIMEST, and OUTITR parameters defined in the NETPAR card are ignored and the frequencies of the surface pipeline network calculations are controlled by WMITN and PWMFRQ cards. When nspnc is equal to one, the surface pipeline network procedure in executed in the same outer iterations and the same timesteps as the predictive well management procedure.

5000.4.4 10-579


10.21 Understanding Injection Network Allocations and Node Pressures in VIP

When using the injection network capability within VIP, it is important to understand how injection rates are allocated to the wells. There are four basic methods of specifying injection targets when using an injection network. These are:

• Specification of individual well targets (QMAX) with no group targets

• Specification of group targets using ITARG

• Specification of group targets using injection regions

• Specification of node targets on the NODES card

When injection network data is defined, VIP will use the network data to calculate rates for all wells connected to the network. If there are no rate constraints on the network NODE cards, these rates will always be pressure limited. If there are rate constraints on the NODE cards, the constraints will be accounted for in the network solution. Once the network is solved VIP will check for non-network group targeting. At this point the individual well rates will be allocated based on normal VIP group targeting methods. If no additional group targets are specified

then each calculated well rate will be checked against the well’ s QMAX target and cut back to the QMAX target if necessary. If the ITARG or INJECTION REGION options are used VIP will take the following steps:

• Check each well 's calculated rate against its QMAX target and cut back the injection rate to QMAX if necessary

• Sum the rates for all wells in the specified group

• If the sum of the rates is less than the specified group target then no further cut backs will be performed

• If the sum of the rates is greater than the specified group target then each well will be allocated a portion of the group 's target as a ratio of its current rate to the sum of the rates.

Regarding reported node pressures, the reported pressure may not correspond to the actual pressure required for the given output node or wellhead pressure. If all wells which branch out from a node are pressure limited then the reported pressure should correspond to the pressure actually required for the given flow rates in the output connections. However, if any wells are rate limited (either through QMAX targets or cut backs due to group targeting), then chokes are implied to exist in the connections to those wells and the reported node pressure will correspond to the MAXIMUM pressure that node requires to deliver the reported flow rates.

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All of the examples shown below contain injection network data as shown below. In summary, there are seven water injection wells connected to a central platform through a series of manifolds and connections. Please refer to this network data when examining the results for the following examples.

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10.21.1 Examples

The input data injection network data for the examples to follow is shown below.

INJECTION NETWORK DATA

PIPESNN NAME DIAMETER THICKNESS ROUGHNESS LENGTH TEMPUP TEMPDW PDCORR1 pipe1 4 0.2 0.001 500 60 60 DUKLER2 pipe2 4 0.2 0.001 2000 60 60 DUKLER3 pipe3 4 0.2 0.001 3500 60 60 DUKLER

CTUBINGNN NAME DIAMETER THICKNESS ROUGHNESS LENGTH DEPTH TEMPUP TEMPDW PDCORR1 TUB1W1 4 0.2 0.001 425 361 150 150 BEGGS2 TUB2W1 4 0.2 0.001 12001 12001 150 150 HAGEDORNCLINK 1 LINK11 1 TUBING2 2 TUBINGCNODESNN NAME ! pmaxi ! qW C1 node1 ! 12000.0 ! 8000 2 node2 ! 2400.0 ! 8500 3 node3 ! 12000.0 ! 7500 4 node4 ! 3600.0 ! 7500 CNODESNN NAME pmaxi ! QW C5 node5 8000.0 ! 30000 CNODCONNODE OUTCON OUTCNT OUTNOD CCnode4 pipe2 pipe node1node1 pipe3 pipe node5node3 pipe3 pipe node5 node2 pipe3 pipe node5 C

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10.1.0.1 Injection Network with No Group Targeting

Example 1 below is a model with an injection network and no group targets. All wells have QMAX targets of 10,000 STBD. From the injection network calculations, wells I1, I2, I3, I4, and I7 have pressure limited rates less than QMAX and wells I5 and I6 have pressure limited rates greater than QMAX. Thus, the actual injected rates for wells I1, I2, I3, I4, and I7 are the calculated pressure limited rates while the injected rates for wells I5 and I6 correspond to the QMAX value. Additionally, since wells I1, I2, I3, I4, and I7 are pressure limited, the pressures reported at nodes 1, 2, 4, and 5 should correspond to the pressures required for the given flow rates. The pressure reported at node 3 will be the MAXIMUM pressure required to deliver the specified rates to wells I5 and I6. One of the well connections will have an implied choke. Additionally, since all wells downstream of node 3 are rate limited, the pressure drop from node 5 to node 3 will not be a true representation of the described equipment because of an implied choke in the connection.

EXAMPLE 1No Group Targeting

WELL GROUP # 1 ()

WELL DAILY INJECTION PRESSURES, PSIA------------------------------- -------------------- ----------------------- PERF LOCATION GRID BOTTOM TUBING ------------- GAS WATER BLOCK HOLE HEADNO. NAME I J LAYER STAT MSCF/D STB/D DATUM DATUM --- -------- --- --- ----- ---- --------- --------- ------- ------ ------ 9 I1 2 10 2- 4 PLIM 0. 9899.88 7821. 8747. 7129. 10 I2 2 29 3- 5 PLIM 0. 5121.88 8130. 12324. 7279. 11 I3 2 20 3- 5 PLIM 0. 9967.41 8099. 10731. 7262. 15 I7 10 10 1- 3 PLIM 0. 9976.28 7886. 10084. 7103. 13 I5 29 10 2- 5 QMAX 0. 10000. 7623. 9073. 4226. 14 I6 18 10 1- 5 QMAX 0. 10000. 7369. 7986. 3157. 12 I4 23 27 4- 5 PLIM 0. 4897.79 8543. 13049. 7983.

========= =========

WELL GROUP TOTALS 0. 59863.

NODES OF GROUP # 1 ()

NODE DAILY INJECTION PRESSURES, PSIA------------------------------- -------------------- -----------------------

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10.1.0.2 Injection Network with Group Targeting Using ITARG

Example 2 is identical to Example 1 with the addition of group targeting through the use of an ITARG card. In this case the group target is 50000 STBD while the sum of the individual well rates (with cut backs for exceeding QMAX targets already accounted for) is 60442.0 STBD. The actual injection rate for each well will thus be the ratio of its current target rate to the sum multiplied against the group target. From the potential report in the output file, the rate for well I1 was 9987.19. Taking this rate as a ratio to the group summation gives well I1 16.524% of the group target, or 8261.2 STBD. Also, from the potential report, the rate for well I5 is 51680 STBD. As this exceeds the wells QMAX target of 10000 STBD, the QMAX target becomes the calculated well rate. This is then taken as a ratio to

total group production to give well I5 16.544% of the group s target injection. This calculates out to 8272.4 STBD. Regarding node pressures, since all wells are on rate target control, all reported pressures will correspond to MAXIMUM pressures required for delivery of the specified rates. For example, the 4670 psia reported at node 2 will be the maximum pressure required to deliver 8261.7 STBD to well I1 and 8266.48 STBD to well I7.

EXAMPLE 2ITARG Group Targeting

WELL GROUP # 1 ()

WELL DAILY INJECTION PRESSURES, PSIA------------------------------- -------------------- ----------------------- PERF LOCATION GRID BOTTOM TUBING ------------- GAS WATER BLOCK HOLE HEADNO. NAME I J LAYER STAT MSCF/D STB/D DATUM DATUM--- -------- --- --- ----- ---- --------- --------- ------- ------ ------ 9 I1 2 10 2- 4 WTAR 0. 8261.71 7675. 8449. 3546. 10 I2 2 29 3- 5 WTAR 0. 4394.29 7952. 11558. 6503. 11 I3 2 20 3- 5 WTAR 0. 8266.34 7900. 10085. 5157. 15 I7 10 10 1- 3 WTAR 0. 8266.48 7725. 9547. 4627. 13 I5 29 10 2- 5 WTAR 0. 8272.31 7507. 8706. 3800. 14 I6 18 10 1- 5 WTAR 0. 8272.31 7298. 7809. 2916. 12 I4 23 27 4- 5 WTAR 0. 4266.56 8293. 12222. 7155.

========= =========




------------- GAS WATER

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10.1.0.3 Injection Regions for Group Targets

Example 3 uses injection regions instead of ITARG cards for group targets. The allocation calculations are identical to those used for ITARG allocations. In this example, target injection rate is controlled by voidage replacement and exceeds the sum of the individual well rates. Thus, no further cut backs are performed and the injection well rates are identical to those shown in example 1. The node pressures reported in this case are identical to those of example 1.

EXAMPLE 3Injection Region

WELL GROUP # 1 ()

WELL DAILY INJECTION PRESSURES, PSIA------------------------------- -------------------- ----------------------- PERF LOCATION GRID BOTTOM TUBING ------------- GAS WATER BLOCK HOLE HEADNO. NAME I J LAYER STAT MSCF/D STB/D DATUM DATUM--- -------- --- --- ----- ---- --------- --------- ------- ------ ------ 9 I1 2 10 2- 4 PLIM 0. 9899.88 7821. 8747. 7129. 10 I2 2 29 3- 5 PLIM 0. 5121.88 8130. 12324. 7279. 11 I3 2 20 3- 5 PLIM 0. 9967.41 8099. 10731. 7262. 15 I7 10 10 1- 3 PLIM 0. 9976.28 7886. 10084. 7103. 13 I5 29 10 2- 5 QMAX 0. 10000. 7623. 9073. 4226. 14 I6 18 10 1- 5 QMAX 0. 10000. 7369. 7986. 3157. 12 I4 23 27 4- 5 PLIM 0. 4897.79 8543. 13049. 7983.

========= =========




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10.1.0.4 Injection Regions with Network Node Targets

Example 4 uses a water constraint on a NODE card with no further group targets. In this case this corresponds to a field target of 50000 STBD. The calculated rates indicate wells I2, I3, I4, and I7 are target limited while QMAX targets of 10000 STBD limit I1, I5, and I6. As the rate limits are actually included as part of the network calculations instead of being applied afterwards, the rate and pressure distributions in the case may be substantially different than in the other 3 cases. Note that node pressures reported in this example appear to be much more physically consistent than in the other 3 examples.

EXAMPLE 4Network Node Targets

WELL GROUP # 1 ()

WELL DAILY INJECTION PRESSURES, PSIA------------------------------- -------------------- ----------------------- PERF LOCATION GRID BOTTOM TUBING ------------- GAS WATER BLOCK HOLE HEADNO. NAME I J LAYER STAT MSCF/D STB/D DATUM DATUM--- -------- --- --- ----- ---- --------- --------- ------- ------ ------ 9 I1 2 10 2- 4 QMAX 0. 10000. 7824. 8760. 4490. 10 I2 2 29 3- 5 QMAX 0. 2607.25 7537. 9687. 4633. 11 I3 2 20 3- 5 QMAX 0. 6924.28 7749. 9580. 4617. 15 I7 10 10 1- 3 QMAX 0. 7880.43 7684. 9422. 4491. 13 I5 29 10 2- 5 QMAX 0. 10000. 7617. 9066. 4777. 14 I6 18 10 1- 5 QMAX 0. 10000. 7364. 7982. 4803. 12 I4 23 27 4- 5 QMAX 0. 2579.98 7741. 10120. 5070.

========= =========




10.21.2 Summary

In summary, it is important to understand that any rate limited well or node connection implies the presence of a choke which is not actually present in the network equipment description. The presence of this implied choke may result in what may seem to be physically inconsistent node pressures as described in Examples 1-3. As a well or node connection becomes rate limited, this implies a choke is being adjusted, which will result in a pressure drop through the choke, which is not accounted for in hydraulic tables, or flow correlation calculations.

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Chapter

11

Automatic Tuning Procedures

11.1 General Information

Automatic tuning procedures have been implemented to improve the match between field observations and simulator predictions of

· well bottomhole pressure,

· well tubinghead pressure,

· pressure in headers and flow lines of the surface pipeline network system,

· well oil, gas, and water production rates.

Parameters of well perforations, tubing strings, and pipelines of the surface pipeline network system can be automatically adjusted from the user specified ranges to improve the match.

“Static” and “dynamic” tuning procedures have been implemented. In “static” tuning procedures TBADJ and WIADJ, parameters of tubing string models (TBADJ) and well indices (WIADJ) are adjusted to match tubinghead or bottomhole pressure in production wells with specified well production rates at one “snapshot” of time. The “static” procedures are executed only in one timestep - the next timestep after the TBADJ and/or WIADJ input. The “dynamic” tuning procedure TUNING can be applied to match field observations in specified time intervals. The TBADJ, WIADJ, and TUNING procedures are described below.

11.2 Well Index Adjustment Procedure (WIADJ) and Tubing String Parameter Adjustment Procedure (TBADJ).

The WIADJ and TBADJ procedures are designed to match well tubinghead pressure (or bottomhole pressure) in production wells with specified well rates. A well index is selected from a specified range in the WIADJ procedure for each “tuned” well. Parameters of the tubing string are selected from specified ranges in the TBADJ procedure. The procedures can be applied for all wells in the model or for a subset of wells at any time during the simulation. They are executed for a user specified number of outer iterations in the next timestep after the WIADJ/TBADJ input. If both TBADJ and WIADJ procedures are applied for some

5000.4.4 11-587


production well, the TBADJ procedure is executed first, then the WIADJ procedure, then the BHPADD parameters are adjusted. In the TBADJ procedure, the gravity pressure gradient is adjusted first, then the friction pressure gradient is modified.

If the tubinghead pressure is specified for some well, a second order optimization procedure is applied to select parameters of the well tubing string and/or well index from the user specified ranges by minimizing the difference between inflow and outflow bottomhole pressure,. The inflow bottomhole pressure is calculated using the specified well rate, gridblock pressure, and inflow relationships in well perforations. The outflow pressure is determined using the specified tubinghead pressure and pressure drop relationships in the well tubing string. Molar rates of the hydrocarbon components required for the definition of the pressure drop in the tubing string are calculated from inflow correlations in well perforations.

If the bottomhole pressure is specified, the well index is calculated from the specified well rate, gridblock pressure, and inflow relationships in well perforations. Only the WIADJ procedure can be applied in this case.

A multiplier of well indices by perforations is determined in the WIADJ procedure. Therefore, the user specified profile of well indices by perforations is maintained and properly scaled. This multiplier is used in all future timesteps, or until well indices for well perforations are redefined using the FPERF, WI, PI, or RFLOW cards.

Correction factors (GRPGCR and FRPGCR) for the gravity and friction pressure gradients in all tubing segments of each “tuned” well are selected in the TBADJ procedure. These correction factors are used in all future timesteps, until they are redefined in the TUBING or PIPES cards.

The tuning procedures can be applied together with the predictive well management option PREDICT NEW. In this case, the tuning procedure is applied after the predictive well management algorithm is used to select the pressure system and gas-lift rate for each tuned well. If the predictive well management option is used in combination with the surface pipeline network option and the optional keyword NOCPRS is included in the TBADJ/WIADJ card, the pressure system is not selected and the existing pressure system is applied for each tuned well. The existing pressure system is determined as the pressure system of the first node in the WELCON card to which the “tuned” well is connected.

If the NEWWEL keyword is included in the TBADJ/WIADJ card, the tuning procedures are executed only for new wells that are selected for drilling in the correspondent time in the automatic drilling option.

The following input is required for the application of the TBADJ and WIADJ procedures:

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1. Define a group of wells that need to be tuned using the WLGRP card. This step is not required if all wells in a reservoir model need to be tuned.

2. Input well rate type (oil, gas, water, liquid, QMULT, etc.) in the PROD card for each “tuned” well. This rate type is applied in the TBADJ and WIADJ procedures.

3. Input instantaneous well rate for each “tuned” well in the QMAX or QMULT card. A well performance can be tuned only if the well rate is larger that zero. The rate of each “tuned” well can be automatically defined as the average well rate in the gathering center to which the well is assigned. To apply this option, keyword RGCAVR must be included in the TBADJ/WIADJ card.

4. Define well tubinghead pressure for each tuned well in the THP card. If the predictive well management option is applied, the tubinghead pressure for the selected pressure system is applied in the tuning procedures. If the surface pipeline option is applied, the tubinghead pressure is calculated using pressure drop relationships in flow lines. The tubinghead pressure input is not required in this case.

5. Input the WIADJ and/or TBADJ cards after the proper DATE card. Define in the WIADJ/TBADJ cards:

· group name or number, if the tuning procedure must be executed for some group of wells;

· ranges of tuning parameters;

· number of outer iterations in which the tuning procedures must be executed;

· convergence parameters of the tuning procedure.

Results of the WIADJ and TBADJ tuning procedures are output in Fortran unit 30.

WIADJ (noutit) (NOCPRS) (SHUTPF)

RGCAVR

RGCAVO

RGCAVG

RGCAVWRGCAVL

(NEWWEL) (wlgrp)

(nwiit mxwic mxwil prrtol pratol aprtol avrmul)

5000.4.4 11-589


TBADJ (noutit)(NOCPRS)(SHUTPF)

RGCAVR

RGCAVO

RGCAVG

RGCAVWRGCAVL

(NEWWEL) (TOTAL) (wlgrp)

(ngpgit nfpgit mxgpgc mxfpgc mnbhpa mxbhpa prrtol pratol aprtol avrmul)

11-590 5000.4.4


Definitions:

noutit Number of outer iterations of a timestep in which WIADJ/TBADJ procedures will be executed. Default is one.

NOCPRS Alpha label indicating that production well assignments to pressure systems must not be changed in outer iterations in which the WIADJ/TBADJ procedure is executed. This keyword can be applied only if the WIADJ/TBADJ procedure is used with the predictive well management option (PREDICT NEW) and the surface pipeline network option.

SHUTPF Alpha label indicating that the status of all perforations will be changed to OFF in the WIADJ/TBADJ procedure for production wells with QMAX=0.

RGCAVR Alpha label indicating that average oil/gas/water/liquid rates in corresponding gathering centers will be applied for tuning production wells with well type PROD O/G/W/LIQUID. The maximum well rates of these wells (QMAX) are set to the average gathering center rate multiplied by the avrmul factor. The average gathering center rates are calculated based on the well production rates in the previous timestep. The RGCAVR option can not be used in the first timestep after a restart.

RGCAVO Alpha label indicating that average oil rates in corresponding gathering centers will be applied in the WIADJ/TBADJ procedures. The well type of “tuned” wells is set to PROD O. The maximum well rates of these wells (QMAX) are set to the average gathering center oil rate multiplied by the avrmul factor. The average gathering center oil rates are calculated based on the well production rates in the previous timestep. The RGCAVO option can not be used in the first timestep after a restart.

RGCAVG Alpha label indicating that average gas rates in corresponding gathering centers will be applied in the WIADJ/TBADJ procedures. The well type of “tuned” wells is set to PROD G. The maximum well rates of these wells (QMAX) are set to the average gathering center gas rate multiplied by the avrmul factor. The average gathering center gas rates are calculated based on the well production rates in the previous timestep. The RGCAVG option can not be used in the first timestep after a restart.

5000.4.4 11-591


RGCAVW Alpha label indicating that average water rates in corresponding gathering centers will be applied in the WIADJ/TBADJ procedures. The well type of “tuned” wells is set to PROD W. The maximum well rates of these wells (QMAX) are set to the average gathering center water rate multiplied by the avrmul factor. The average gathering center water rates are calculated based on the well production rates in the previous timestep. The RGCAVW option can not be used in the first timestep after a restart.

RGCAVL Alpha label indicating that average liquid rates in corresponding gathering centers will be applied in the WIADJ/TBADJ procedures. The well type of “tuned” wells is set to PROD LIQUID. The maximum well rates of these wells (QMAX) are set to the average gathering center liquid rate multiplied by the avrmul factor. The average gathering center liquid rates are calculated based on the well production rates in the previous timestep. The RGCAVL option can not be used in the first timestep after a restart.

NEWWEL Alpha label indicating that the WIADJ/TBADJ procedure will be applied only for new wells selected for drilling in the automatic drilling procedure. The well group number/name wlgrp must be input in this case. The new wells will be automatically assigned to this group, while all existing wells will be automatically removed.

TOTAL Alpha label indicating that correction factors for total pressure gradient in well tubing strings will be determined in the TBADJ procedure. Maximum number of iterations and maximum total correction factor can be input as ngpgit and mxgpgc, respectively. Parameters nfpgit and mxfpgc are ignored.

wlgrp Well group name or number. The WIADJ/TBADJ procedure will be executed for all production wells in the specified well group. The procedure will be executed for all production wells if wlgrp is not input.

nwiit Maximum number of iterations of the WIADJ optimization procedure. Default is 10.

mxwic Maximum change of well index, in percent (%). It is assumed that the well index multiplier can be changed in the range from 1/(1+.01mxwic) to (1+.01mxwic). Default is 50%.

11-592 5000.4.4


mxwil Maximum perforation well index value. Default is 30.

prrtol Pressure relative convergence tolerance. If the absolute value of relative differences between inflow and outflow bottomhole pressure is less than prrtol in some iteration, the WIADJ/TBADJ procedure converges. Default is .0001.

pratol Pressure absolute convergence tolerance, psia (kPA). If the absolute value of differences between inflow and outflow bottomhole pressure is less than pratol, the WIADJ/TBADJ procedure converges. Default is 3 psia.

aprtol Adjustment parameter relative convergence tolerance. If the absolute value of the relative change of a tuning parameter is less than aprtol, the WIADJ/TBADJ procedure converges. Default is .0001.

avrmul Average gathering center rate multiplier. This parameter is applied only if one of the RGCAVR, RGCAVO, RGCAVG, RGCAVW, or RGCAVL options is used. Default is one.

ngpgit Maximum number of iterations used in the TBADJ procedure for the calculation of the gravity pressure gradient correction factor. Default is 10.

nfpgit Maximum number of iterations used in the TBADJ procedure for the calculation of the friction pressure gradient correction factor. Default is 10.

mxgpgc Maximum change of the gravity pressure gradient, in percent (%). It is assumed that the gravity pressure gradient correction factor can be changed in the range from 1/(1+.01mxgpgc) to (1+.01mxgpgc). Default is 30%.

mxfpgc Maximum change of the friction pressure gradient, in percent (%). It is assumed that the friction pressure gradient correction factor can be changed in the range from 1/(1+.01mxfpgc) to (1+.01mxfpgc). Default is 30%.

mnbhpa Minimum bottomhole pressure adjustment BHPADD, psia (kPA). The default value is 0.

mxbhpa Maximum bottomhole pressure adjustment BHPADD, psia (kPA). The default value is 0.

5000.4.4 11-593


NOTE: If Parameters NOCPRS, SHUTPF, RGCAVR, RGCAVO, RGCAVG, RGCAVW, RGCAVL, NEWWEL, noutit, wlgrp, prrtol, pratol, and/or avrmul are input in both TBADJ and WIADJ cards in the same simulation time, values of these parameters from the last card will be applied in both TBADJ and WIADJ procedures.

Example:

CC Apply the WIADJ procedure for Wells WELL1 and WELL2CWLGRP 1 TUNE_WELLS WELL1 WELL2C Number Use Average Apply Existing Tuned WellC Outer GC Rate Pressure System Group NameC Iterations Well Assignments WIADJ 1 RGCAVR NOCPRS TUNE_WELLSC Maximum Number Maximum Change Maximum Index inC of Iterations of Well Index % Well Perforations 100 30 20

11-594 5000.4.4


11.3 Dynamic TUNING Procedure

A tuning procedure has been implemented to match field measurements in specified time intervals by adjusting parameters of the well perforation, tubing string, and surface pipeline network models.

The simulations are automatically repeated several times (passes) in the specified time interval. Values of history matching relative error functions are determined in each pass. If these values are less than the user specified tolerances, or the number of the passes exceeds its limit, the tuning procedure is terminated. Otherwise, new values of adjusted parameters are selected at the end of each pass and the next pass is executed.

The start of the tuning time interval is defined by the TIME/DATE card after which the TUNING card is included. The end of the tuning time interval is determined by next TIME/DATE card following the ENDTUNING card.

The history matching relative error functions for oil, gas, and water production rates of the i-th production well are defined as follows:

qi

cqi tj QqiC

tj QqiM

tj –

j 1=

N

cqi tj QqiM

tj

j 1=

N

----------------------------------------------------------------------- q o g w. = =

Where:

QqiM

tj q=o,g,w , are measurements of oil, gas, and water production rates of the

i-th well at the simulation time tj. They are input using the QMULT card after the

corresponding TIME/DATE card;

QqiC

tj q=o,g,w , are calculated oil, gas, and water production rates of the i-th

well at the simulation time tj. They are determined at the end of the timestep after

each TIME/DATE card in the tuning time interval;

N is the number of TIME/DATE cards in the tuning time interval;

cqi tj q=o,g,w , are the error function coefficients which can be input by the user

using the TERC cards. The default values of these coefficients are one.

The error function for gas-oil ratio or gas-liquid ratio can be applied instead of the error function for gas rate using the GOR or GLR keywords in the TUNING card.

5000.4.4 11-595


The error function for water cut or water-gas ratio can be applied instead of the error function for water rate using the WCUT or WGR keywords in the TUNING card.

The history matching relative error functions for pressure at well bottomhole, tubinghead, and nodes of the surface pipeline network system are determined as follows:

pi

cpi tj PpiC

tj PpiM

tj –

j 1=

N

cpi tj PpiM

tj

j 1=

N

---------------------------------------------------------------------- p b t n. = =

Where:

PpiM

tj p=b,t,n, are measurements of bottomhole pressure, tubinghead pressure,

and node pressure in the i-th well or i-th node at the simulation time tj. They are

input using the TBHP, TTHP, and TPRND cards after the corresponding TIME/DATE card;

PpiC

tj p=b,t,n, are calculated bottomhole pressure, tubinghead pressure, and

node pressure in the i-th well or i-th node at the simulation time tj. They are

determined at the end of the timestep after each TIME/DATE card in the tuning time interval;

cpi tj p=b,t,n, are the error function coefficients which are input using the TBHP,

TTHP, and TPRND cards. Defaults of these coefficients are one.

If the RELERR keyword is included in the TUNING card, the error functions are calculated as follows:

qi cqi tj Qqi

Ctj Qqi

Mtj –

QqiM

tj --------------------------------------------- q

j 1=

N

o g w. = =

A similar expression is used for the pressure error functions in this case.

The tuning procedure is terminated when values of the relative error functions are less than the tolerances specified by the user in the MAXRER and MAXRNE cards or the numbers of passes for the different steps of the tuning procedure exceeds the maximum values.

The following steps are executed sequentially in the tuning procedure:

11-596 5000.4.4


1. Tune parameters of well perforations and well indices. The maximum number of simulator passes in this step (maxnip) is input by the user in the TUNING card. In each pass, the simulation is executed in the time interval defined by the TUNING and ENDTUNING cards.

2. Set M to the maximum node level.

3. Tune parameters of output flow lines for all nodes of Level M.

4. Reduce node Level M by one. Repeat Step 3 if M is larger than one.

5. Tune parameters of flow lines connecting well heads to nodes of the surface pipeline network system, if M is equal to one.

6. Tune parameters of well tubing strings. The maximum number of simulator passes (maxnil) in each of Steps 3, 5, and 7 is specified by the user in the TUNING card.

If parameter maxnil is input as a negative number, the parameters of flow lines, well lines, and tubing strings are tuned simultaneously. In this case, the absolute value of parameter maxnil is the maximum number of passes in this step.

If keyword RNP is included the TUNING card, pressures in nodes of Levels M+1, M+2, ... are reset to their measured values in Step 3 of the tuning procedure. Otherwise, the calculated values are applied.

If keyword RTHP is included the TUNING card, tubinghead pressures in production wells are reset to their measured values in Step 6 of the tuning procedure. Otherwise, the calculated values are applied.

A range of parameter multiplier changes must be specified to tune any parameter. A maximum parameter change dmax (in percent) is input by the user. It is assumed that the parameter multiplier can be changed in the range from max((1-.01dmax), (1 + .01dmin)), to (1+dmax). The minimum parameter changes for well perforations and flowlines are input in the MNPFCF and MNFLCF cards.

The well indices can be adjusted within the user specified ranges to match bottomhole pressure measurements in production wells. The ranges of the well indices are specified in the TWELL cards.

If the bottomhole pressure measurements are not available, they can be estimated by the simulator, using tubinghead pressure and pressure drop relationships in well tubing strings. The keyword TCBHP must be included in the TUNING card to use this option.

5000.4.4 11-597


The following well perforation parameters can be tuned within the user specified ranges to improve the history match between field measurements and predictions of the oil, gas, and water production rates:

• endpoints of gas and water relative permeability curves in well perforations,

• permeability thickness (KH) values in well perforations,

• water and gas relative permeabilities at residual oil saturation in well perforations.

The ranges of the well perforation parameters are specified in the TWELL and/or TFPERF cards.

The following parameters of tubing strings can be adjusted within the user specified ranges to match well inflow and outflow bottomhole pressures:

• roughness,

• length,

• diameter,

• pressure gradient,

• pressure drop in well chokes.

The ranges of the well tubing string parameters are specified in the TTUBING cards.

The following parameters of well flowlines connecting wellheads to nodes of the surface pipeline network system can be adjusted within the user specified ranges to match measurements of well tubinghead pressure:

• roughness coefficient,

• length,

• diameter,

• pressure gradient,

• pressure drop in well chokes.

The ranges of the well flowline parameters are specified in the TWLFL cards.

The following parameters of output flowlines of nodes can be adjusted within the user specified ranges to match measurements of node pressure:

• roughness coefficient,

11-598 5000.4.4


• length,

• diameter,

• pressure gradient.

The ranges of the parameters of the node output flowlines are specified in the TSPN cards.

Inactive perforations with status OFF specified in the FPERF card can be automatically turned ON if predicted oil, gas or water production rates in the well are significantly less than their measurements. The MINRER card is used to activate this option.

The calculated adjustment factors for well perforation, tubing string, well flowline, and pipeline parameters can be printed if keywords PRADJFPERF and/or PRTUBSPN are included in the TUNING card. These adjustment factors can be input to the simulator in the cards ADJFPERF, ADJTUBING, ADJWLFL, ADJSPN, and ADJWI. Therefore, the TUNING procedure can be executed in one history matching run to calculate the adjustment factors and print them. In all other runs, these adjustment factors can be used as input and the TUNING procedure is not required.

The adjustment factors calculated in different passes of the tuning procedure can be output if debug print is requested using keyword PRDEBUG in the TUNING card.

The tuning procedure results for wells and/or nodes can be output to two spreadsheet files if keywords PRWLRP and/or PRNDRP are included in the TUNING card. The measurements and predictions of the oil, gas, and water well production rates, bottomhole pressure, and tubinghead pressure for different times in the tuning time interval are output to the well spreadsheet file (Fortran unit 30). The measurements and predictions of the oil, gas, and water rates and pressure in the nodes of the surface pipeline network system are output to the node spreadsheet file (Fortran unit 69).

Input to the TUNING procedure can be divided into the following groups:

• Determination of general parameters (tuning time interval, types of error functions, and output requests) (TUNING, ENDTUNING).

• Convergence parameters (MAXRER, MAXRNE).

• Definition of tuning parameter ranges (TWELL, TFPERF, TTUBING, TWLFL, TSPN, MNPFCF, MNFLCF).

• Request for the activation of inactive perforations (MINRER), if it is required.

• Field measurements (QMULT, TBHP, TTHP, TPRND).

5000.4.4 11-599


• Adjustment factors (ADJFPERF, ADJTUBING, ADJWLFL, ADJSPN, ADJWI).

The convergence parameters (MAXRER, MAXRNE), the tuning parameter ranges (TWELL, TFPERF, TTUBING, TWLFL, TSPN, MNPFCF, MNFLCF), and the MINRER card must be input immediately following the TUNING card as one package of data.

The field measurements (QMULT, TBHP, TTHP, TPRND) can be input at any time in the tuning time interval.

The adjustment factors (ADJFPERF, ADJTUBING, ADJWLFL, ADJSPN, ADJWI) can be input independently from the TUNING procedure at any time during a simulation.

11.3.1 General Parameters (TUNING, ENDTUNING)

The start of the tuning time interval is defined by the TIME/DATE card after which the TUNING card is included. The end of the tuning time interval is determined by the next TIME/DATE card following the ENDTUNING card.

TUNING (maxnip maxnil) GRATEGORGLR

WRATEWCUTWGR

(param)

ENDTUNING

Definitions:

maxnip Maximum number of simulation passes used for tuning parameters of well perforations. Default is 10.

maxnil Maximum number of simulation passes used for tuning parameters in EACH level of the surface pipeline network structure. If the maxnil is negative, the parameters of flowlines, well lines, and tubing strings are tuned simultaneously. In this case, the absolute value of maxnil is the maximum number of the simulation passes used for tuning of the surface pipeline network parameters. Default is 5.

GRATE Alpha label indicating that well gas production rates will be applied in error function calculations. This is the default.

11-600 5000.4.4


GOR Alpha label indicating that well gas-oil ratio will be applied in error function calculations.

GLR Alpha label indicating that well gas-liquid ratio will be applied in error function calculations.

WRATE Alpha label indicating that well water production rates will be applied in error function calculations. This is the default.

WCUT Alpha label indicating that well water cut will be applied in error function calculations.

WGR Alpha label indicating that well water-gas ratio will be applied in error function calculations.

The following additional parameters may be entered:

RELERR Alpha label indicating that relative error functions will be applied.

RNP Alpha label indicating that measured pressure in a node will be used for tuning parameters in all nodes from lower levels. If this keyword is not included, the calculated pressure will be applied.

RTHP Alpha label indicating that measured well tubinghead pressure will be used for tuning parameters of tubing strings. If this keyword is not included, the calculated tubinghead pressure is applied.

TCBHP Alpha label indicating that output bottomhole pressure calculated from pressure drop calculations in tubing strings will be used for tuning well indices. If this keyword is not included, the measured bottomhole pressure is applied.

PRWLRP Alpha label indicating that a well report in spreadsheet format will be generated in Fortran unit 30. Measurements and predictions of oil, gas, and water well production rates, bottomhole pressure, and tubinghead pressure for different times in the tuning time interval are included in this report before and after tuning.

PRNDRP Alpha label indicating that a node report in spreadsheet format will be generated in Fortran unit 69. Measurements and predictions of oil, gas, and water well production rates, and pressure in nodes for different times in the tuning time interval are included in this report before and after tuning.

5000.4.4 11-601


Example:

CC Start the TUNING procedure at Jan. 1, 1998CDATE 01 01 1998TUNING GOR WCT PRWLRP PRNDRP PRADJFPERF PRTUBSPN............CC End the TUNING procedure at Jun 1, 1998CENDTUNINGDATE 01 06 1998

11.3.2 Convergence Tolerances (MAXRER and MAXRNE)

The MAXRER and MAXRNE cards must be input in the group of data immediately following the TUNING card.

MAXRER oilrtl (gasrtl watrtl bhprtl)

MAXRNE prnrtl (biortl)

PRADJFPERF Alpha label indicating that adjustment factors for well perforation parameters and well indices will be printed in the output file at the end of the tuning procedure. The adjustment factors are printed in the format for cards ADJFPERF and ADJWI.

PRTUBSPN Alpha label indicating that adjustment factors for parameters of well tubing strings, well flowlines, and surface pipeline network will be printed in the output file at the end of the tuning procedure. The adjustment factors are printed in the format for cards ADJTUBING, ADJWLFL, and ADJSPN.

PRFPER Alpha label indicating that well perforation parameters in FPERF format will be printed in the output file at the end of the tuning procedure.

PRDEBUG Alpha label indicating a debug report will be printed in the output file at the end of each pass of the tuning procedure.

11-602 5000.4.4


Definitions:

oilrtl Relative tolerance for oil rate error functions, fraction. Default is 0.01.

gasrtl Relative tolerance for gas rate error functions, fraction. Default is 0.01.

watrtl Relative tolerance for water rate error functions, fraction. Default is 0.01.

bhprtl Relative tolerance for bottomhole pressure error functions, fraction. Default is 0.01.

prnrtl Relative tolerance for tubinghead error functions and pressure error functions in nodes of the surface pipeline network system, fraction. Default is 0.01.

biortl Relative tolerance for differences in inlet and outlet bottomhole pressure, fraction. Default is 0.01.

Examples:

MAXRER 0.002 0.002 0.002 0.002

MAXRNE 0.002 0.002

5000.4.4 11-603


11.3.3 Parameter Ranges (TWELL, TFPERF, TTUBING, TWLFL, TSPN, MNPFCF, MNFLCF)

The TWELL, TFPERF, TTUBING, TWLFL, TSPN, MNPFCF, and MNFLCF cards must be input in the group of data immediately following the TUNING card.

Ranges of adjusted parameters of well perforations are specified in the TWELL and TFPERF cards.

Ranges of adjusted parameters of well tubing strings are specified in the TTUBING card.

Ranges of adjusted parameters of well flowlines connecting wellheads to nodes of the surface pipeline network system are specified in the TWLFL card.

Ranges of adjusted parameters of flowlines connecting nodes of the surface pipeline network system are specified in the TSPN cards.

Minimum values of correction factors for perforation parameters are specified in the MNPFCF card.

Minimum values of correction factors for flowline parameters are specified in the MNFLCF card.

A parameter will not be adjusted if a range of parameter changes is not defined in the appropriate TWELL, TFPERF, TTUBING, TWLFL, or TSPN card. Therefore, the default values of the maximum parameter changes dmax are zero.

TWELL (well_list)(DWI) (DSWR) (DSGR) (DKH) (DKRW) (DKRG)(dmax) (dmax) (dmax) (dmax) (dmax) (dmax)

TFPERFWELL (DSWR) (DSGR) (DKH) (DKRW) (DKRG)wn (dmax) (dmax) (dmax) (dmax) (dmax)The last card is repeated as necessary to describe all the perforations for each well being tuned.

TTUBING (well_list)(DDIAM) (DLENGTH) (DROUGH) (DPRGR)(dmax) (dmax) (dmax) (dmax)

TWLFL (well_list)(DDIAM) (DLENGTH) (DROUGH) (DPRGR)(dmax) (dmax) (dmax) (dmax)

11-604 5000.4.4


TSPN (node_list)(DDIAM) (DLENGTH) (DROUGH) (DPRGR)(dmax) (dmax) (dmax) (dmax)

MNPFCF dminDSWR (dminDSGR dminDKRW dminDKRG dminDKH dminDWI)

MNFLCF dminDROUGH (dminDDIAM dminDLENGTH dminDPRGR)

Definitions:

well_list List of production wells for which maximum parameter changes are input in the TWELL, TTUBING, or TWLFL cards (see Section 1.5.2). If the well list is not input, the maximum parameter changes are assumed to apply to all production wells.

node_list List of nodes for which maximum parameter changes are input in the TSPN card. If the node list is not input, the maximum parameter changes are assumed to apply to all nodes of the surface pipeline network system.

wn Well number or well name (TFPERF card). The well number or name must be entered for each data card. For multiple completions in a single well, the alpha label X must be substituted for the well number or well name on each data card after the first.

WELL Alpha label indicating that this field will contain a well number, a well name, or the alpha label X.

DWI Alpha label indicating that this field will contain a maximum well index change.

DSWR Alpha label indicating that this field will contain a maximum change of endpoints of the water relative permeability curve in well perforations.

DSGR Alpha label indicating that this field will contain a maximum change of endpoints of the gas relative permeability curve in well perforations.

DKH Alpha label indicating that this field will contain a maximum change of permeability thicknesses in well perforations.

DKRW Alpha label indicating that this field will contain a maximum change of the water relative permeability at residual oil saturation in well perforations.

5000.4.4 11-605


Examples:

CC Allow changes of well indices, endpoints of water relative permeability curves, C water relative permeability, and KH values in well perforations of C Wells WELL1 and WELL2 by 20%, 10%, 20%, and 30%, respectively.CTWELL WELL1 WELL2DWI DSWR DKRW DKH20 10 20 30CC Allow changes of roughness coefficients and pressure gradient in tubing C strings of all wells by 50% and 40%

DKRG Alpha label indicating that this field will contain a maximum change of the gas relative permeability at residual oil saturation in well perforations.

DDIAM Alpha label indicating that this field will contain a maximum change of diameter of well tubing (TTUBING), well output flowline (TWLFL), or node output flowline (TSPN).

DLENGTH Alpha label indicating that this field will contain a maximum change of length of well tubing (TTUBING), well output flowline (TWLFL), or node output flowline (TSPN).

DROUGH Alpha label indicating that this field will contain a maximum change of roughness coefficient in well tubing (TTUBING), well output flowline (TWLFL), or node output flowline (TSPN).

DPRGR Alpha label indicating that this field will contain a maximum change of pressure gradient in well tubing (TTUBING), well output flowline (TWLFL), or node output flowline (TSPN).

dmax Maximum change of the corresponding parameter, percent (%). It is assumed that the parameter multiplier can be changed in the range from max((1-.01dmax), (1 + .01dmin)) to (1+.01dmax). Default is zero.

dmin Minimum change of the corresponding parameter, percent (%). It is assumed that the parameter multiplier can be changed in the range from max((1-.01dmax), (1 + .01dmin)) to (1+.01dmax). The value of dmin can not be positive and must be larger than-100. Default is -99.9.

11-606 5000.4.4


CTTUBINGDROUGH DPRGR50 40

11.3.4 Activation of Inactive Perforations (MINRER)

The MINRER card must be input in the group of data immediately following the TUNING card.

MINRER roilmin (rgasmin rwatmin rkhmin frfoil frfgas frfwat)

Definitions:

roilmin Minimum oil relative error, fraction. An inactive perforation in a production well is considered for activation only if the oil relative error function (calculated minus measured oil production rate) is negative and its absolute value is larger than roilmin. Default is 1.E+10.

rgasmin Minimum gas relative error, fraction. An inactive perforation in a production well is considered for activation only if the gas relative error function (calculated minus measured gas production rate) is negative and its absolute value is larger than rgasmin. Default is 1.E+10.

rwatmin Minimum water relative error, fraction. An inactive perforation in a production well is considered for activation only if the water relative error function (calculated minus measured water production rate) is negative and its absolute value is larger than rwatmin. Default is 1.E+10.

rkhmin Minimum relative permeability thickness (KH) value, fraction. An inactive perforation in a production well is considered for activation only if the ratio of KH * WIL in this perforation to the maximum KH * WIL in active perforations is larger than rkhmin. Default is 0.1.

5000.4.4 11-607


Examples:

MINRER 1.E+10 0.1 0.1 0.1 1.E+10 0.2 0.2

frfoil Minimum oil fractional flow coefficient, fraction. An inactive perforation in a production well is considered for activation only if the oil relative error function in the well is negative, its absolute value is larger than roilmin, the perforation relative KH value is larger than rkhmin, and the oil fractional flow coefficient in this perforation is larger than frfoil. Default is 0.1.

frfgas Minimum gas fractional flow coefficient, fraction. An inactive perforation in a production well is considered for activation only if the gas relative error function in the well is negative, its absolute value is larger than rgasmin, the perforation relative KH value is larger than rkhmin, and the gas fractional flow coefficient in this perforation is larger than frfgas. Default is 0.1.

frfwat Minimum water fractional flow coefficient, fraction. An inactive perforation in a production well is considered for activation only if the water relative error function in the well is negative, its absolute value is larger than rwatmin, the perforation relative KH value is larger than rkhmin, and the water fractional flow coefficient in this perforation is larger than frfwat. Default is 0.1.

11-608 5000.4.4


11.3.5 Field Measurements and Error Function Coefficients (QMULT, TBHP, TTHP, TPRND, TERC)

Field measurements of well bottomhole pressure, well tubinghead pressure, and pressure in nodes (TBHP, TTHP, TPRND) as well as error function coefficients (TERC) can be input at any time in the tuning time interval defined by the TUNING and ENDTUNING cards.

Field measurements of oil, gas, and water rates in production wells can be input using the QMULT cards.

If field measurements (TBHP, TTHP, TPRND, QMULT) are not input after some TIME/DATE card in the tuning time interval, values from the previous input are applied. Before the tuning time interval, they are set to zero. It is assumed that a measurement is not available if a zero value of this measurement is input.

TBHP well_list bhp1 bhp2... bhpn (efc1 efc2... efcn)

TTHP well_list thp1 thp2... thpn (efc1 efc2... efcn)

TPRND node_list prnd1 prnd2...prndn (efc1 efc2... efcn)

TERC (well_list) (OIL) (GAS) (WATER) (efc) (efc) (efc)

Definitions:

well_list List of production wells for which field measurements and/or error function coefficients are input in the TBHP, TTHP, or TERC cards (see Section 1.5.2). If the well list is not input in the TERC card, the error function coefficients are assumed to apply to all production wells.

node_list List of nodes for which pressure measurements and error function coefficients are input in the TPRND card.

5000.4.4 11-609


NOTE: The number of the bhp/thp/prnd values must equal to the number of wells/nodes in the well/node list.

Examples:

CC Input rate and pressure measurements for Wells WELL1 and WELL2CQMULT WELL1 WELL2 200 320 !Oil rates 6210 7340 !Gas rates 4 400 !Water ratesTBHP WELL1 WELL2 4230 4920TTHP WELL1 WELL2 1210 1310CC Pressure measurements in Node NODE3CTPRND NODE3 650

bhp Bottomhole pressure measurement in a production well, psia (kPA).

thp Tubinghead pressure measurement in a production well, psia (kPA).

prnd Node pressure measurement, psia (kPA).

OIL Alpha label indicating that this field will contain an error function coefficient for the well oil rate.

GAS Alpha label indicating that this field will contain an error function coefficient for the well gas rate.

WATER Alpha label indicating that this field will contain an error function coefficient for the well water rate.

efc Coefficient of the corresponding error function.

11-610 5000.4.4


11.3.6 Adjustment Factors (ADJWI, ADJFPERF, ADJTUBING, ADJWLFL, ADJSPN)

The ADJWI, ADJFPERF, ADJTUBING, ADJWLFL, and ADJSPN cards can be input at any time during a simulation.

ADJWI well_list adfc1 adfc2... adfcn

ADJFPERFWELL (DSWR) (DSGR) (DKH) (DKRW) (DKRG)wn (adfc) (adfc) (adfc) (adfc) (adfc)The last card is repeated as necessary to describe all the perforations for each well for which parameters are being adjusted.

ADJTUBING (well_list)(DDIAM) (DLENGTH) (DROUGH) (DPRGR)(adfc) (adfc) (adfc) (adfc)

ADJWLFL (well_list)(DDIAM) (DLENGTH) (DROUGH) (DPRGR)(adfc) (adfc) (adfc) (adfc)

ADJSPN (node_list)(DDIAM) (DLENGTH) (DROUGH) (DPRGR)(adfc) (adfc) (adfc) (adfc)

Definitions:

well_list List of production wells for which simulation parameters are being adjusted (see Section 1.5.2).

node_list List of nodes for which simulation parameters of output flowlines are being adjusted.

wn Well number or well name. The well number or name must be entered for each data card. For multiple completions in a single well, the alpha label X must be substituted for the well number or well name on each data card after the first.

WELL Alpha label indicating that this field will contain a well number, a well name, or the alpha label X.

5000.4.4 11-611


Examples:

CC Adjust well indices, endpoints of water relative permeability curves, C water relative permeability, and KH values in well perforations of C Well WELL1 by 18%, 4%, 17%, and -5%, respectively.

DSWR Alpha label indicating that this field will contain an adjustment factor for endpoints of the water relative permeability curve in well perforations.

DSGR Alpha label indicating that this field will contain an adjustment factor for endpoints of the gas relative permeability curve in well perforations.

DKH Alpha label indicating that this field will contain an adjustment factor for permeability thicknesses in well perforations.

DKRW Alpha label indicating that this field will contain an adjustment factor for the water relative permeability at residual oil saturation in well perforations.

DKRG Alpha label indicating that this field will contain an adjustment factor for the gas relative permeability at residual oil saturation in well perforations.

DDIAM Alpha label indicating that this field will contain an adjustment factor for diameter of well tubing (ADJTUBING), well output flowline (ADJWLFL), or node output flowline (ADJSPN).

DLENGTH Alpha label indicating that this field will contain an adjustment factor for length of well tubing (ADJTUBING), well output flowline (ADJWLFL), or node output flowline (ADJSPN).

DROUGH Alpha label indicating that this field will contain an adjustment factor for roughness coefficient in well tubing (ADJTUBING), well output flowline (ADJWLFL), or node output flowline (ADJSPN).

DPRGR Alpha label indicating that this field will contain an adjustment factor for pressure gradient in well tubing (ADJTUBING), well output flowline (ADJWLFL), or node output flowline (ADJSPN).

adfc Adjustment factor of the corresponding parameter, percent (%). The parameter multiplier will be defined as 1 + .01adfc.

11-612 5000.4.4


CADJWI WELL1 18

ADJFPERFWELL DSWR DKRW DKHWELL1 4 17 -5X 4 17 -5CC Adjust roughness coefficient and pressure gradient in a tubing C string of Well WELL1 by 27% and 32%, respectively.CADJTUBING WELL1DROUGH DPRGR27 32

11.3.7 Output of Automatic Tuning Results

The adjustment factors for well perforation, tubing string, well flowline, and pipeline parameters calculated in the TUNING procedure can be printed if keywords PRADJFPERF and/or PRTUBSPN are included in the TUNING card.

The adjustment factors calculated in different passes of the tuning procedure can be output if the debug print is requested using keyword PRDEBUG in the TUNING card.

The tuning procedure results for wells and/or nodes can be output to two spreadsheet files if keywords PRWLRP and/or PRNDRP are included in the TUNING card. The measurements and predictions of the oil, gas, and water well production rates, bottomhole pressure, and tubinghead pressure for different times in the tuning time interval are output to the well spreadsheet file (Fortran unit 30). The measurements and predictions of the oil, gas, and water rates and pressure in the nodes of the surface pipeline network system are output to the node spreadsheet file (Fortran unit 69).

5000.4.4 11-613


11-614 5000.4.4

Chapter

12

Gas Field Operations (GFO) Option

12.1 Introduction

The Gas Field Operations (GFO) option provides a set of tools which have been developed to assist the engineer in simulating various forms of gas deliverability requirements found in many gas sales contracts. The principle factors involved are as follows:

1. Annual contract -- For the number of years specified for the GFO contract, the simulation time is advanced one year at a time, rather than through the use of TIME or DATE cards. The contract must start on the first day of a month.

2. Multiple contracts -- The annual contract may actually be a set of contracts, each corresponding to an area in the simulation model. All contracts start on the same date.

3. DCQ - Daily Contracted Quantity -- This is the average daily rate for each contract that must be delivered for the entire contract year.

4. Seasonality profile factors -- Monthly adjustment factors to adjust the DCQ for the different seasons. Actual production for each month for each contract is the DCQ times the profile factor for the month.

5. Swing factors -- There are several different variations with the use of the swing factors, but in general and with varying conditions, the field, or each contract area, must be capable of producing at a rate of DCQ times the swing factor. If not, the DCQ must be reduced to a value which would allow this excess capacity to be available at any time during the contract year. These swing factors are specified monthly, just like the profile factors, and should be equal to or greater than the profile factors.

6. Sales gas rate -- For GFO, the gas targets (DCQ's) are sales gas rates, accounting for gas production minus gas consumption (fuel gas) and shrinkage gas, plus extraneous gas imported from outside of the field.

7. ACQ - Annual Contracted Quantity -- This is equal to DCQ times the number of days in the contract year.

8. Estimation of delivery capacity (maximum deliverability when all targets are removed).

5000.4.4 12-615


9. Multiple simulations of each contract year -- Normally at least two passes are made through each contract year, depending on which DCQ contract option (DCQCON) is being used. Pass 1 will be testing to ensure that the swing constraints for each contract can be met and, if so, pass 2 will be made using the seasonality profile factors. If the swing constraints cannot be met for each contract, the appropriate DCQ values are reduced, and another pass 1 cycle is performed.

10. Simulator output -- No output will be produced during the pass 1 simulations, with the exception of the basic timestep summary lines so that the engineer can monitor the progress of the simulation. Requested reports, using data not included in an Annual Scheduling File (ASF), will be generated after the completion of the pass 2 simulation of the annual contract, and any new input data may be entered at the end of any contract. If additional reports and/or data changes are required during a contract year, they must be set up in an Annual Scheduling File.

12.2 Gas Field Operations Data (GFO)

This set of data controls the functionality of the gas contract for one or more years. For the initial introduction, all data lines must be specified (optional data elements may be defaulted). However, for subsequent entries such as extending a contract, only the number of years is required. The current simulation time at the beginning of a contract must correspond to the first day of a month.

GFO NYEARS (MAXCYC) (MONTH) (CUMTOL) (RDFAC)

nyears (maxcyc)YESNO

(cumtol) (rdfac)

(CONTRACT (area))

(SWING swJAN ... swDEC)(PROFILE prJAN ... prDEC)(TAKE tkJAN ... tkDEC)(DCQ) (DCQCON) (DCQLIM) (DCQANT)

(dcq)

YEARINSTANT

ACQmonthNO

(dcqlim) (dcqant)

(CONTRACT (area))

ENDGFO

Definitions:

12-616 5000.4.4


NYEARS Alpha label indicating that the entry in the appropriate position on the following card is the number of years for the contract(s). This entry is required.

MAXCYC Alpha label indicating that the entry in the appropriate position on the following card is the maximum number of DCQ reduction cycles in the first pass.

MONTH Alpha label indicating that the entry in the appropriate position on the following card denotes whether the simulation is forced to end a timestep at the beginning of each month.

CUMTOL Alpha label indicating that the entry in the appropriate position on the following card is the tolerance to use when checking the gas production target(s).

RDFAC Alpha label indicating that the entry in the appropriate position on the following card is the additional DCQ reduction factor.

nyears Number of years in the contract(s). This entry is required.

maxcyc Maximum number of DCQ reduction cycles in the first pass of each contract year. When this number of cycles has been performed, the second pass is performed. Default is 5 if the MAXCYC entry is never included on a GFO card.

YES Alpha label indicating that the simulation is forced to end a timestep at the beginning of each month.

NO Alpha label indicating that the simulation is not forced to hit the beginning of each month. This is the default if the MONTH entry is never included on a GFO card.

cumtol Tolerance to use when checking the gas production target(s) fraction. The DCQ will be reduced, and another cycle performed, if the actual gas produced is not within the tolerance of the required amount. Default is 0.9999 if the CUMTOL entry is never included on a GFO card.

rdfac Additional DCQ reduction factor, fraction. When the DCQ is reduced based on actual production divided by required production, it is further multiplied by this factor to help speed convergence. Default is 0.99 if the RDFAC entry is never included on a GFO card.

CONTRACT Alpha label indicating that subsequent data (up to another CONTRACT card or the ENDGFO card) applies to this

5000.4.4 12-617


contract. At least one CONTRACT must have been entered in the first set of GFO data.

area Area number or name. Specifying this data implies that the multiple contracts option will be used, and that all the production wells in this area are part of this contract group. If this data is not entered, all production wells in the field are considered to be in the single contract group.

SWING Alpha label indicating that the following 12 values on this card are monthly swing factors for this contract.

sw Monthly swing factors for this contract, starting with January. There must be 12 values. Default is 1.0 for each factor if SWING is never included in GFO data.

PROFILE Alpha label indicating that the following 12 values on this card are the monthly profile factors for this contract.

pr Monthly profile factors for this contract, starting with January. There must be 12 values. Default is 1.0 for each factor if PROFILE is never included in GFO data.

TAKE Alpha label indicating that the following 12 values on this card are the monthly gas take factors for this contract.

tk Monthly gas take factors for this contract, starting with January fraction. There must be 12 values. Default is 1.0 for each factor if TAKE is never included in the GFO data.

DCQ Alpha label indicating that the entry in the appropriate position on the following card is the initial daily contracted quantity (DCQ) for this contract. This must be entered in the first set of GFO data.

DCQCON Alpha label indicating that the entry in the appropriate position on the following card is the DCQ swing condition for this contract. This must have been entered in the first set of GFO data.

DCQLIM Alpha label indicating that the entry in the appropriate position on the following card is the DCQ limiting factor per cycle for this contract.

DCQANT Alpha label indicating that the entry in the appropriate position on the following card is the anticipated DCQ reduction factor per year for this contract.

12-618 5000.4.4


dcq Initial daily contracted quantity for this contract, MSCF/D (SM3/D). This must have been entered in the first set of GFO data.

One of the next 5 entries must have been entered in the DCQCON position in the first set of GFO data.

YEAR Alpha label indicating that the field, or contract area, must be able to produce at the DCQ multiplied by the monthly swing factor for the entire contract year.

INSTANT Alpha label indicating that the field, or contract area, must be able to raise its production rate from DCQ times profile to DCQ times swing for an instant at any time in the contract year.

ACQ Alpha label indicating that the field must be able to produce at DCQ times swing continuously until it has produced the annual contracted quantity (ACQ). This may not be used with the multiple contracts option.

month Possible values: JAN, FEB, MAR, APR, MAY, JUN, JUL, AUG, SEP, OCT, NOV, DEC. The field must be able to produce at DCQ times swing continuously until it has produced a fraction of its annual contracted quantity proportional to the sum of profile factors up to the end of the specified month. This may not be used with the multiple contracts option.

NO Alpha label indicating that the swing requirement will not be tested. The DCQ will not be reduced even if the field cannot produce at DCQ times profile.

dcqlim DCQ limiting factor per cycle for this contract, fraction. The DCQ may not be reduced by more than this factor times the original DCQ for each cycle for this set of GFO data. Default is 0.0 (allowing unlimited reduction) if the DCQLIM entry is never included in GFO data.

dcqant Anticipated DCQ reduction factor per year for this contract, fraction. At the beginning of each subsequent contract year, the current DCQ will be further multiplied by this factor. Default is 1.0 if the DCQANT entry is never included in GFO data.

ENDGFO Alpha label indicating the end of this set of GFO data. Required. Simulation of the GFO contract year(s) begins immediately at this point.

NOTE: 1. Almost all of the data that can be entered with the GFO card is remembered when subsequent GFO data is entered. The only

5000.4.4 12-619


required data in subsequent GFO data is NYEARS.

2. If area is specified on any CONTRACT card, then all CONTRACT cards must have an area specified.

3. The data DCQ, DCQCON, DCQLIM, and DCQANT may all be entered on one card or may be entered in any combination on multiple cards.

4. When the maximum number of cycles, maxcyc, has been performed during the first pass, the second pass is performed with the reduced DCQ calculated at the end of that last cycle.

5. A contract year must start on the first day of a month.

6. Simulator output (e.g. WPLOT 1, PRINT WELLS TIME) that is active at the time GFO data is entered is handled as follows:

a. TIME - the output is generated at the end of eachcontract year.

b. TNEXT - the output is generated at the end of the last yearof the contract.

c. freq - the data is ignored and is not remembered whenthe contract ends.

12-620 5000.4.4


12.3 Annual Scheduling File (ASF)

An Annual Scheduling File (ASF) is required if any data changes or output reports are required during the contract year. Once introduced, the ASF will remain in effect for subsequent contract years, until replaced by another ASF.

ASF(recurrent data)(MONTH month)(recurrent data)(MONTH month)

.

.

.ENDASF

Definitions:

ASF Alpha label indicating the beginning of the Annual Scheduling File.

MONTH Alpha label indicating that a timestep will end at exactly the beginning of the specified month.

month Month at which the timestep will end. Possible values: JAN, FEB, MAR, APR, MAY, JUN, JUL, AUG, SEP, OCT, NOV, DEC.

recurrent data Any recurrent data allowed by the simulator except for the keywords listed in the notes below.

ENDASF Alpha label indicating the end of the Annual Scheduling File.

NOTE: 1. The data within the Annual Scheduling File is read and applied during each GFO contract year.

2. A new ASF/ENDASF set of data replaces the previously specified set of data.

3. To turn off the Annual Scheduling File, enter ASF/ENDASF with no data in between.

4. Data entered between the ASF card and the first MONTH card (or the ENDASF card if no MONTH card) applies at the beginning of each contract year.

5. A MONTH card is not allowed for the month at which the contract begins.

5000.4.4 12-621


6. If multiple MONTH cards are entered, they must occur chronologically following the month at which the contract begins.

7. The following data cards are not allowed within an ASF/ENDASF set of data: TIME, DATE, STOP, END, WELL, WREST, WLASTR, BLITZ, CBLITZ, TUNING, GFO, ASF.

8. Simulator output entered within the Annual Scheduling File is handled as follows:

a. TIME - the output is generated at the beginning of eachmonth specified on a MONTH card and at theend of each contract year.

b. TNEXT - the output is generated at the beginning of thenext month specified on a MONTH card or at theend of the contract year, whichever occurs first.

c. freq - the output is generated every freq timesteps.

12-622 5000.4.4

Chapter

13

Local Grid Refinement1

13.1 Introduction

The use of the Local Grid Refinement (LGR) option in VIP-EXECUTIVE requires only a relatively small amount of additional input data. This involves primarily the location of the well perforations relative to the grid refinements, which must be specified unless the well is located entirely in the ROOT grid. Other input data provide options for significantly improving the CPU run time performance, particularly for multi-grid system runs involving mixed levels of implicitness.

13.2 Formulation Options

In VIP-THERM, only IMPLICIT is allowed.

In VIP-COMP and VIP-ENCORE, two formulation options are available for use with multi-grid systems; IMPES and IMPLICIT. The formulation option may be switched at the beginning of any restart run. If no formulation specification is entered in a run starting from initial conditions, the IMPES form of the finite difference equations will be used. If no formulation specification is entered in a restart run, the formulation will be the same as used during the previous run. Unless otherwise specified, the same formulation option will be used for all of the grids. However, significant CPU time savings may be achieved by varying the level of implicitness to be used with each of the grids.

13.2.1 Formulation Specification by Grid (IMPGRID) (VIP-COMP or VIP-ENCORE)

If entered, the IMPGRID/ENDIMPGRID data must occur along with other utility data and should follow any IMPES/IMPLICIT data.

The IMPGRID keyword indicates that the following lines will declare the finite difference formulation to be used for specific grids. This data must be followed by an ENDIMPGRID keyword.

1. Available as a separately licensed option.

5000.4.4 13-623


IMPGRIDgridnamei formulationiENDIMPGRID

Definitions:

IMPGRID Alpha label indicating the beginning of the formulation specification data by grid.

gridnamei Name of the grid, as specified in the grid refinement data in the initialization data set.

formulationi Type of finite difference formulation to be used for this grid. It must be either IMPES or IMPLICIT. This can be changed at the start of any restart run.

ENDIMPGRID Alpha label indicating the end of the formulation specification data by grid.

Example:

IMPLICITCRESTART 0CIMPGRIDROOT IMPESOILCOLMN IMPESENDIMPGRIDCSTART

In this example, the IMPLICIT card first sets the formulation to IMPLICIT for all grids. Then the ROOT grid and the OILCOLMN grid are reset to IMPES, leaving all the radial well grids using the IMPLICIT formulation.

13.2.2 Turn Off Pressure Interpolation (NOPINT)

If entered, the NOPINT card must occur along with other utility data. This option is not saved on the restart file and thus must be respecified at the beginning of each run.

The NOPINT card is used to turn off the default pressure interpolation calculation across grids. The default procedure is to do linear interpolations for pressures in the parent block boundaries opposite refined gridblocks. This interpolation is performed in all three directions, if there is communication in the respective directions. However, for comparisons to results from previous simulator versions,

13-624 5000.4.4


this procedure may be turned off, resulting in the usage of constant pressures across the parent gridblocks. In VIP-THERM the NOPINT card also turns off an equivalent temperature interpolation calculation.

NOPINT

13.3 Activate/Deactivate Grids (Not available in VIP-THERM)

At initial conditions, all grid refinements are assumed to be active. However, any refinement may be deactivated and/or reactivated at any time during the simulator run. This feature may be used to achieve significant CPU time savings by activating refined grids only during the simulation time at which there is significant activity occurring within the grid. If a grid refinement is deactivated, then all sub-refinements [children] of the grid are also deactivated. When a grid refinement is activated, then all grid refinements which contain it [parents] are also activated.

Only the pore volumes and transmissibilities at initial conditions are preserved and reinstated as necessary, as grid refinements are deactivated and reactivated. When a grid refinement that has been active for one or more timesteps is deactivated, new values for the unknowns (pressure, composition, saturations, etc.) are calculated for each of the gridblocks that had been refined in the parent grid, such that precise material balance is maintained. When a grid is activated after having been inactive for one or more timesteps, the unknowns of the parent gridblocks are propagated directly to the refined gridblocks, again preserving material balance. The activation/deactivation procedure is performed after all input for the time interval has been read.

ACTIVATE gridname1 gridname2 . . . . gridnamenDEACTIVATE gridname1 gridname2 . . . . gridnamem

Definitions:

ACTIVATE Alpha label indicating that the following named grids are to be activated.

gridnamei Names of the grid refinements to be activated. If this list contains only the keyword ALL, then all grid refinements will be activated.

DEACTIVATE Alpha label indicating that the following named grids are to be deactivated.

gridnamej Names of the grid refinements to be deactivated.

5000.4.4 13-625


Example:

ACTIVATE ALLDEACTIVATE WELL21 WELL28 WELL35

13.4 Timestep Controls

For multi-grid systems which may involve mixed levels of implicitness, it may be necessary to have separate sets of maximum change parameters for both the iteration and the timestep. To accomplish this, two new optional keywords have been implemented: DTMPL and ITNMPL. When a DT keyword is read, the maximum change parameters for both the IMPES grids and the IMPLICIT grids are set to the values specified on the DT card. Also when an ITNLIM keyword is read, the maximum change parameters for both the IMPES grids and the IMPLICIT grids are set to the values specified on the ITNLIM card. If different values are desired for the IMPLICIT grids, the DTMPL and ITNMPL keywords must be used to specify the maximum change parameters for the IMPLICIT grids only.

13.4.1 Timestep Controls for IMPLICIT Grids (DTMPL) (VIP-COMP or VIP-ENCORE)

The DTMPL card defines the maximum changes allowed during the timestep for IMPLICIT grids only. The values are order dependent, but only as many as necessary need be entered. They will not affect the values used for IMPES grids.

DTMPL dpmax (dsmax) (dvmax) (dzmax) (card 1)

BOTH

DTONLY

MAXONLY

NONE

BOTH

DTONLY

MAXONLY

NONE

BOTH

DTONLY

MAXONLY

NONE

BOTH

DTONLY

MAXONLY

NONE

(card 2)

Definitions:

dpmax Maximum pressure change allowed during a timestep in IMPLICIT grids, psi (kPa). Default is 500 psi.

dsmax Maximum water saturation change allowed during a timestep in IMPLICIT grids. Default is 0.1.

dvmax Maximum gas saturation change allowed during a timestep in IMPLICIT grids. Default is 0.1.

dzmax Maximum change in total mole fraction allowed during a timestep in IMPLICIT grids. Default is 0.1.

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The optional second card can be input to modify the usage of the new maximum changes as to whether the appropriate maximum will be used for checking the maximum change over the timestep, calculating the next timestep size, both of these, or none.

Example:

DT -1 1 93 100 .03 .10 .04 DTMPL 300 .10 .10 .10

13.4.2 Iteration Controls for IMPLICIT Grids (ITNMPL) (VIP-COMP or VIP-ENCORE)

The ITNMPL card defines the maximum changes allowed for each outer iteration for IMPLICIT grids only. The values are order dependent, but only as many as necessary need be entered. They will not affect the values used for IMPES grids.

ITNMPL dplim (dswlim) (dsglim)(dzlim)

Definitions:

dplim Maximum pressure change allowed during any single outer iteration in IMPLICIT grids, psi (kPa). Default is 300 psia.

dswlim Maximum water saturation change allowed during any single outer iteration in IMPLICIT grids. Default is 0.1.

dsglim Maximum gas saturation change allowed during any single outer iteration in IMPLICIT grids. Default is 0.1.

dzlim Maximum change in primary phase composition allowed during any single outer iteration in IMPLICIT grids. Default is 0.1.

Example:

ITNLIM 1 10 100 .03 .10 .04 ITNMPL 300 .10 .10 .10

5000.4.4 13-627


13.5 Matrix Solution Option (CBLITZ)

A new matrix solver package, CBLITZ, has been developed specifically for the composite system of linear equations. CBLITZ is an iterative solver, using the Preconditioned Generalized Minimum Residual (GMRES) method. CBLITZ must be used for all multi-grid systems and for three-dimensional radial single-grid systems using the FLOW360 feature. Other single-grid systems may still use BLITZ, EXCEL, or GAUSS.

CBLITZ (param1) . . . (paramn) (card 1)(value1) . . . (valuen) (card 2)

Definitions:

CBLITZ Alpha label indicating that the CBLITZ solver is to be used for this run.

ITER A CBLITZ iteration summary should be printed. No entry should be made on card 2 corresponding to this entry.

NOITER A CBLITZ iteration summary should not be printed. This is the default. No entry should be made on card 2 corresponding to this entry.

NORTH Maximum number of orthogonalizations used by the GMRES method. Default is 10.

NIT Maximum number of CBLITZ iterations allowed. Default is 20.

NITG Maximum number of subgrid iterations on each grid to be performed for each CBLITZ iteration. Default is 1 for Cartesian refinements and 3 for radial refinements.

NOPTG Ordering option for line constraints for each grid. The grid ordering can have a significant effect upon convergence. Typically a grid should be ordered first in the direction of the strongest transmissibility, then in the next strongest direction, etc. Also it may be beneficial to order first in the direction of the smallest grid dimension, then in the direction of the next smallest grid dimension, etc. A value of 0 allows CBLITZ to determine the ordering for each grid. Default is 0.

0 = Automatic determination.

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NBEPS Composite grid preconditioning:

0= Sequential preconditioning1= BEPS preconditioning2= FAC preconditioning

Default is 2 when JCPR=1; default is 0 otherwise.

NHARM Preconditioning method for the subgrids. The current implementation utilizes nested factorization, and the input value is not used.

JCPR Constrained pressure residual method (CPR) option:

0= No pressure predictor step.1= Use pressure predictor step.Default is 1 if any grid is implicit.

RTOL Norm (EUCLIDEAN) residual reduction ratio convergence tolerance parameter for the composite system. Default is .005.

RTOLG Norm (EUCLIDEAN) residual reduction ratio convergence tolerance parameter for each grid. Default is .005.

ADJTOL Turns on the adjustable linear tolerance algorithm with default values for TOLMN, TOLMX, TOLST and TOLEX. No entry should be made on card 2 corresponding to this entry.

TOLMN Turns on the adjustable linear tolerance algorithm and specifies the minimum value of linear tolerance to be used throughout the simulation. Default is RTOL so that, if RTOL is defaulted, then TOLMN defaults to 5.E-03 but, if RTOL is specified, then TOLMN is set to the specified RTOL value. TOLMN must range between 0.0 and 1.0.

TOLMX Turns on the adjustable linear tolerance algorithm and specifies the maximum value of linear tolerance to be used throughout the simulation. Default is 0.5. TOLMX must range between 0.0 and 1.0.

5000.4.4 13-629


TOLST Turns on the adjustable linear tolerance algorithm and specifies the value of linear tolerance to be used in the first Newton step of each timestep. Default is max(TOLMX, 5 * RTOL). TOLST must be less than TOLMX and greater than or equal to 0.0.

TOLEX Turns on the adjustable linear tolerance algorithm and specifies the value of the exponent in the power law used to control the reduction of the linear solver tolerance as the Newton iteration nears convergence. Default is 3.0. TOLEX must be nonnegative.

NOTE: The pressure predictor step (JCPR=1) should only be used in conjuction with the implicit formulation.

Example:

CBLITZ NORTH RTOL NITG RTOLG 20 .002 3 .002

13.5.1 CBLITZ Parameters by Grid (CBLGRID)

Three of the CBLITZ parameters can be modified on a grid-by-grid basis, providing additional flexibility and efficiency for the solution of the linear system of equations. If this data is introduced, it must immediately follow the CBLITZ data. Any one, two, or all three of the parameter names may be introduced in any order following the keyword CBLGRID. These parameters may be particularly helpful with multi-grid systems involving mixed levels of implicitness. This data must be followed by an ENDCBLGRID keyword.

CBLGRID (NITG) (NOPTG) (RTOLG) gridname1 (nitg1) (noptg1) (rtolg1)gridname2 (nitg2) (noptg2) (rtolg2)

. . . .gridnamen (nitgn) (noptgn) (rtolgn) ENDCBLGRID

13-630 5000.4.4


Definitions:

CBLGRID Alpha label indicating that the following data will modify some of the CBLITZ parameters on a grid- by-grid basis.

gridnamei Name of the grid.

NITG Alpha label indicating that this column of data will change the maximum number of subgrid iterations for the specified grid.

nitgi Maximum number of subgrid iterations to be performed for this grid for each CBLITZ iteration.

NOPTG Alpha label indicating that this column of data will change the ordering for the specified grid.

noptgi Gridblock ordering for the specified grid.

RTOLG Alpha label indicating that this column of data will change the grid convergence tolerance for the specified grid.

rtolgi Grid convergence tolerance for the specified grid.

ENDCBLGRID Alpha label indicating the end of the CBLITZ parameter input by grid.

Example:

CBLGRID NITGROOT 1OILCOLMN 1ENDCBLGRID

From the previous example, the NITG parameter was first initialized to 3 for all grids. Then with the above example data, the NITG parameter is reset to 1 for both the ROOT grid and the OILCOLMN grid. Thus the CBLITZ solver would perform a maximum of three subgrid iterations on each of the implicit radial well grids and one subgrid iteration on the ROOT and OILCOLMN grids for each CBLITZ iteration.

5000.4.4 13-631


13.6 Well Data Options

For multi-grid systems, it may be necessary to specify in which grid(s) that the well resides, in addition to the standard IW and JW well location. If no additional data is entered, the well is assumed to be in the ROOT grid, and the IW and JW are relative to that grid. However, if the well perforations are in one or more of the grid refinements, then the grid name must be specified on either the WELL card or the FPERF card. If the well perforations are all within the same grid, then the grid may be specified on the WELL card. If the well perforations are in two or more grids, then the grid must be specified for each of the perforations, along with the proper IW and JW relative to the grid.

13.6.1 Well Name and Location (WELL)

WELL . . . . (GRID) . . . .. . . . (gridname) . .

Definitions:

GRID Alpha keyword indicating that this field will contain the grid name in which the well is perforated.

gridname Name of the grid in which this well is perforated. If entered, the iw, jw well location must be relative to this grid.

Example:

WELL N NAME IW JW GRID 1 P1 X X P1 2 P2 X X P2 3 P3 26 23 OILCOLMN 4 P4 X X P4 5 P5 5 10 OILCOLMN 6 P6 X X P6 8 P8 X X P8 9 P9 X X P9 10 P10 X X P10 11 P11 X X P11 13 P13 X X P13 15 P15 X X P15


FPERF WELL . . . . (GRID) . . . .

. . . . (gridname) . .

13-632 5000.4.4


Definitions:

GRID Column heading for gridname, the name of the grid in which this well perforation is located. The iw, jw and l, if entered for the perforation, must be relative to this grid.

wil d

lnradbradw------------ skin Sr+ +

--------------------------------------------------------=

NOTE: 1. If the well is in a radial grid and numerical values for (IW, JW) have not been specified in the FPERF data or in any previous WELL name and location data, then perforations will be automatically generated in IW=1, for JW=1,2,...,NTHETA for the radial grid.

2. For radial wells the alpha label X can be specifed for IW and JW.

3. This is for radial refinements and root grid with FLOW360 option. For perforations in the first ring (IW=1) the following applies:

where d is the gridblock angle. The default radb is the gridblock centroid (log mean radius with BLOCKTR option). The default radw is ri.

Example:

FPERFWELL L KH GRID IW JW 1 1 4320 P1 X X X 2 972 P1 X X 2 1 872 P2 X X X 2 84 P2 X X 4 1 648 P4 X X 6 1 2800 P6 X X X 2 112 P6 X X

5000.4.4 13-633


13.7 Assign Gridblocks to Injection Regions (INJREGN)

See Section 4.5.6 for further discussion.

INJREGN nir (NOCASCADE)i1 i2 j1 j2 k1 k2 (gridname)(data card may be repeated as necessary)

Definitions:

NOCASCADE Alpha label indicating that this region number should not be cascaded to any grids located within the gridblocks defined in the data specified.


NOTE: If NOSASCADE is not entered, the region number will be cascaded to lower level grids contained within these ranges.

13.8 Options Restricted to Use with Single-Grid Systems Only

n Boundary Flux Option

n Pattern Element Option

13.9 Arbitrary Gridblock Connections (FTRANS)

FTRANS (GRID name1 (name2)) i1 j1 k1 i2 j2 k2 t tt (repeat as necessary)

Definitions:


name1 Name of grid1. Default is ROOT.

name2 Name of grid2. Default is name1.

See Section 8.6.5 for additional definitions.

13-634 5000.4.4


13.10 Override Modification (OVER)


i1 i2NX

j1 j2NY

k1 k2NZ

#v (v2) (#v (v2)) (#v (v2)) (#v (v2))


Definitions:


name Name of the grid. Default is ROOT.


NOTE: Operations only apply to the specified grid, i.e., no propagation.

13.11 Value Override (VOVER)


i1 i2NX

j1 j2NY

k1 k2NZ

(op)

values as necessary

Definitions:


name Name of the grid. Default is ROOT.


NOTE: Operations only apply to the specified grid, i.e., no propagation.

5000.4.4 13-635


13-636 5000.4.4

Chapter

14

00000Tracer Option1

14.1 Introduction

This is short description of a set of tools which have been developed to improve and expand the simulation capabilities in the analysis and interpretation of tracer tests and in the design and performance analysis of secondary recovery projects. The tools are built around the particle tracking method which allows accurate simulation of tracer flow associated with convection and physical dispersion. The method is nearly numerical dispersion free and allows accurate simulation of tracer flow in field scale simulation. The algorithm is implemented in VIP-EXECUTIVE and allows simulation of tracer flow within the framework of three-dimensional, multi-phase, non-steady state reservoir simulation. In addition to accurate simulation of tracer flow the software allows: (1) tracking of fronts in flooding operations; (2) construction of three-dimensional flow trajectories and streamlines of velocity field; (3) calculation of the areal sweep; (4) visualization and animation of tracer flow. Both gas and water tracers are allowed in the tracer option. Tracers can be phase partitioning or non-partitioning . Tracers can partition between gas/oil, oil/water, gas/oil/water or gas/water (see note following Section 14.2.3). 00

14.2 VIP Tracer Option Input Data Description

All tracer option related input cards in the simulation modules fall into three sections: Utility Data, Recurrent Data, and Output Control Data. The run control data of the Utility Data section include three parameters in the DIM card which change the default dimension of the parameters used in the tracer option and the FRONT card which invokes the front tracking option. The TRACER card and the TRACIN card are recurrent data. The TRACER card defines some parameters and specifies options which will be used in the simulation run. The TRACIN card controls the tracer injection. And, finally, the Output Control Data database section includes the WTRACE card and the WTRPLOT card which control output to the tracer, and the PRINT TRACER card which controls tracer option output to the simulator output file. 00

1. Available as a separately licensed option. Not available in VIP-THERM.

5000.4.4 14-637



The card allows the user to change the default dimensions on any run starting from initial conditions (time zero) and to increase the dimensions passed on to a restart. 00

DIM NPRTM NTRCEM NTRWLMnprtm ntrcem ntrwlm

00 Definitions:

NPRTM Alpha label for the maximum of the total number of tracer particles to be defined in this run. Default is 5000.

nprtm The value of the corresponding parameter.

NTRCEM Alpha label for the maximum number of tracers to be defined in this run. Default is 2.

ntrcem The value of the corresponding parameter.

NTRWLM Alpha label for the maximum number of simultaneous tracer injectors to be defined in this run. (Maximum number of TRACIN cards for this run. See section 12.2.4). Default is 2.

ntrwlm The value of the corresponding parameter.

14.2.2 Activate Front Tracking Option (FRONT)

00 If entered the FRONT card must occur along with other utility data.

The FRONT card activates the front tracking option. It allows tracking of the injected water front in a unit mobility ratio displacement (water-water displacement) or the water front in an oil displacement by water. To use the front tracking option the user must inject tracer (TRACIN card) at the moment when the water injection starts. By default, activation of the tracer option in VIP-CORE does not automatically activate the front tracking option. This option cannot be used with the gas tracer option. 00

FRONT (WWDSP)

00 Definition:

WWDSP Optional alpha label indicating that this is water-water displacement. Default is oil-water displacement.

14-638 5000.4.4


14.2.3 Define Parameters for Tracer Option (TRACER)

This group of input cards defines some parameters for tracer option calculations. The TRACER card indicates the beginning of the group. The remaining cards must closely follow. Most of the cards are optional. The card order within the group is not important. This group of cards belongs to the recurrent utility data cards of the simulation modules and can appear several times within the input data set if it is necessary to redefine some of the parameters later into the run. 00

TRACER ntrcw ntrcg (nsubt)(NAMES name1 name2 ... namentrcw + ntrcg)KVALUE ntr

trname Kw

P KW

Kg

cname1 cname2 fac P KG

ISOWGO

dspl

ANISO

WGO

dspl dspt

(BOUNDARY xdir ydir zdir)(CENTER)(ORIGIN)(TRCOFF)

Definitions: 00

ntrcw Number of water tracers to be used in the run.

ntrcg Number of gas tracers to be used in the run.

nsubt Number of tracer substeps per simulator timestep. Default is 1.

NAMES Alpha label indicating that names of tracers follow on this card.

namei Name of tracer i. An alphanumeric label containing up to 8 characters.

KVALUE Alpha label for specifying the k-value of a partitioning tracer. Default is non partitioning.

5000.4.4 14-639


ntr Tracer identification number.

trname Tracer identification name.

Kw Oil/water tracer partitioning k-value (constant).Definition: (Mole fraction of tracer in the oil phase)/(Mole fraction of tracer in the aqueous phase)Kw = -0.5 is interpreted as Kw = infinite, and the tracer is a non partitioning oil tracer.

Kg Gas/oil tracer partitioning k-value (constant).Definition: (Mole fraction of tracer in the gas phase)/(Mole fraction of tracer in the oil phase).Kg = -0.5 is interpreted as Kg = infinite, and the tracer is a non partitioning gas tracer.

cname1 Hydrocarbon component name used to compute Kg internally by the simulator. Kg = k-value of cname1.

cname2 Hydrocarbon component name used to compute Kg internally by the simulator as a linear combination of the k-values of cname1 and cname2.Kg = (k-value of cname1)* fac +

(k-value of cname2)*(1-fac)

fac Weighting factor for computing Kg from the k-values of cname1 and cname2.

P, KW, KG Alpha labels indicating that (pressure, kvalue) table data pairs will follow. When entering both KW and KG data, either can be terminated by a value of -1 in the appropriate pressure column. The model interpolates these data in the ln(K) vs. ln(P) space.

ISO Alpha label which turns on isotropic dispersion calculations. Defines the value of dispersivity coefficient.

ANISO Alpha label which turns on anisotropic dispersion calculations. Defines the values of longitudinal and transversal dispersivity coefficients.

W Alpha label indicating the dispersivity specified is for the water phase. Default applies to all three phases.

G Alpha label indicating the dispersivity specified is for the gas phase. Default applies to all three phases.

O Alpha label indicating the dispersivity specified is for the oil phase. Default applies to all three phases.

dspl Longitudinal dispersivity, ft. Default is 0.

14-640 5000.4.4


dspt Transversal dispersivity, ft. Default is 0.

BOUNDARY Alpha label which defines boundary conditions in the x, y, and z directions. Physical dispersion of tracer is modeled by appropriate random adjustment of particle positions at the end of the timesteps. This adjustment may bring a particle outside the model. Particles can also cross the boundary with convective flow due to large timesteps.The user can prevent this by defining appropriate boundary conditions.

xdir, ydir, zdir Alpha labels (FLOW, NOFLOW) which define boundary conditions for dispersion calculations in the x, y, and z directions, respectively. The FLOW label indicates that particles can cross the boundary, and the NOFLOW label specifies that particles will be reflected by the boundary. Default is NOFLOW.

CENTER Alpha label which overrides default well locations in the grid blocks.

ORIGIN Alpha label specifying that there is a well at the origin of the radial grid system.

TRCOFF Alpha label which turns off tracer option calculation.

NOTE: 1. For a water tracer, Kg is optional on the KVALUE line, while for a gas tracer, Kw is optional on the KVALUE line.

2. For any tracer, if both Kw and Kg are defined, then three phase, gas/oil/water partitioning will be modeled. (This will reduce to gas/water partitioning if the oil phase is missing)

3. Gas/water tracer partitioning can be modeled as described by note 2, or by setting Kw = 1, and defining Kg as the ratio (mole fraction of tracer in the gas phase)/(mole fraction of tracer in the water phase), or by setting Kg = 1, and defining Kw as the ratio (mole fraction of tracer in the gas phase)/(mole fraction of tracer in the water phase).

Example:

00 TRACER 0 3 2 ! FOR 3 GAS TRACERSNAMES C-14 Co-60 SR-90CENTERISO 1.BOUNDARY FLOW FLOW NOFLOW

14.2.4 Inject Tracer (TRACIN)

The TRACIN card defines the tracer injections. Parameters in the card are order

5000.4.4 14-641


dependent. 00

TRACIN ntr itrwell npart (nplanes) (trcvol) (trconc) (al1 al2)

00 Definitions:

ntr A tracer number from the list of tracers, or a tracer name from those defined by the NAMES card.

itrwell The well number or name of the well injecting the tracer.

npart The number of tracer particles to be introduced with this tracer injection.

nplanes The number of planes along which to place new particles. Default is 1 plane.

trcvol The volume of traced water or gas to be injected, in bbls. Default is 1 bbl.

trconc The concentration of tracer injected. Default is 1.0

al1 al2 The values of two angles which define the sector near the well to place the particles. The angles are counter-clockwise with the positive direction of x-axis, degrees. al1 is the starting angle, al2 is the sector angle. Default is the full circle around the well.

14-642 5000.4.4


14.2.5 Write Map Records to Database (WTRACE)

00 This card controls map output to the tracer data base.

WTRACE

TIME

TNEXT

OFF

freq

00 Definitions:

TIME Alpha label that causes the record to be written each time a TIME or DATE card is encountered. Default is not to print on the basis of TIME or DATE cards.

TNEXT Alpha label that causes the record to be written only the next time a TIME or DATE card is encountered. Default is not to print on the basis of the next TIME or DATE card.


freq A number that causes the record to be written after every freq timesteps. Default is 99999.

14.2.6 Write Plot Records to Database (WTRPLOT)

00 This card controls map output to the tracer data base.

WTRPLOT

TIME

TNEXT

OFF

freq

00 Definitions:



5000.4.4 14-643




14.2.7 Write Records to Tracer File (WTRDBG)

00 This card controls output to the tracer output file (Fortran unit 38).

WTRDBG

TIME

TNEXT

OFF

freq

00 Definitions:





14-644 5000.4.4


14.2.8 Write Tracer Summary (PRINT TRACER)

The PRINT card has an additional alpha label which causes output of the tracer summary report. 00

PRINT TRACER

TIME

TNEXT

OFF

freq

00 Definition:

TRACER Alpha label that causes the tracer summary report to be written to the simulator output file.





5000.4.4 14-645


14-646 5000.4.4

Chapter

15

00000Parallel Computing1

15.1 Parallel Grid Assignment

15.1.1 Introduction

Assignment of parallel processors to grids is a critical task to maintain parallel efficiency. The goal of processor assignment should be to maximize efficeincy while at the same time minimizing the required parallel resources. Since a red/black ordering is used in the linear equation solution, for any parallel simulation the maximum efficiency for the solver is achieved by assigning two neighboring grids to each processor so that calculations on “red” and/or “black” grids are performed in an alternating fashion on the same processor. On the other hand, for compositional simulations in which the solver CPU time is not dominant, the maximum parallel performance can be obtained with each grid being assigned to a separate processor.

15.1.1 Processor Mapping File

The mapping of grids to processors is assigned in the standard input file to the simulator (i.e., fortran Unit 6). This file is generated automatically by the PAVA job submittal panel. For command line execution the following information is required. The file contains four types of information: the location of the EXECFIL for VIP-EXEC, the location of restart files for the parallel restarts, the grid and processor information and the assignment of processors to grids. Each line of input data for the mapping file is described below: 00

execfilrestartnproc ngrids idebuggridi processorgridi+1 processor. .. .. .gridngrids processor

1. Not yet available in VIP-THERM.

5000.4.4 15-647


Definitions: 00

execfil Fully qualified name of the execfil.dat file input to VIP-EXEC.

restart Fully qualified name of the restart file read by VIP-EXEC.

nproc Number of processors.

ngrids Number of grids.

idebug Debug control flag.

idebug = 0 for no debug outputidebug = 1 will produce debug output from all

processors.

gridi Particular grid assigned to a particular processor. Grids are identified by numbers as printed in the process id file of VIP-CORE, (fortran unit 15).

processor Processor number assigned to grid. Processor number can be any number between 1 and nproc inclusive.

Example Data: 00

8 grids plus ROOT grid and 4 processors

Grid2 Grid3 Grid4 Grid5

Grid6 Grid7 Grid8 Grid9

15-648 5000.4.4


The mapping file would appear as follows:

/vip/usr/xxx/execfil.dat/vip/usr/xxx/casei.rst4 9 01 12 13 14 25 26 37 38 49 4

The ROOT grid is always grid number 1.

5000.4.4 15-649


15-650 5000.4.4

Chapter

16

00000RESOLVE® Control of VIP Simulation

16.1 Turn On RESOLVE® Control of VIP Simulation (RESOLVE)

The RESOLVE card is used to turn on the link between VIP and Petroleum Experts' RESOLVE.

RESOLVE

NOTE: If the RESOLVE keyword is encountered in the recurrent data input file, the remainder of the recurrent data is ignored since the RESOLVE keyword indicates that the simulation will be under total control of RESOLVE from that point forward in time. Minimally, the VIP-EXECUTIVE input data should contain the definition of all wells (including perforations and well type) to be used in the simulation at the beginning of the recurrent data and an end time sufficiently large to go beyond the ultimate simulation end time of the controlling program RESOLVE. The wells are linked to the equivalent RESOLVE wells in the RESOLVE setup phase (See RESOLVE User's Guide). After encountering the RESOLVE keyword VIP-EXECUTIVE assumes that the RESOLVE program will provide all injection and production rates for the remainder of the simulation. Eventually, RESOLVE will terminate the simulation when one of its stopping criteria has been met. A likely scenario for the VIP-EXECUTIVE input data will include the history match portion of the simulation followed by the RESOLVE keyword and a large end time or date. This would allow VIP-EXECUTIVE to perform the history match and for RESOLVE to take over the simulation after that point to include the effect of Petroleum Experts' GAP® surface network model, for example. After encountering the RESOLVE keyword, VIP-EXECUTIVE's workover and well shut-in controls encountered before the RESOLVE keyword would still be active and would override any RESOLVE-supplied rates or pre-RESOLVE perforations.

5000.4.4 16-651


16-652 5000.4.4

Chapter

v

References

1. Beggs, H. Dale, Gas Production Operations, OGCI Publications, pp. 103-104 (1984).

2. Peaceman, D.W., "Interpretation of Well-Block Pressures in Numerical Reservoir Simulation", Soc. Pet. Engr. J., pp. 183-194 (June, 1978).

3. Jain, A.K., "An Accurate Explicit Equation for Friction Factor", J. Hydraulics Div. ASCE, Vol 2, No. Hy5 (May, 1976).

4. Wallis, J.R., "Incomplete Gaussian Elimination as a Preconditioning for Generalized Conjugate Gradient Acceleration", SPE 12265 presented at the Seventh SPE Symposium on Numerical Simulation, San Francisco (1983).

5. Wallis, J.R., Kendall, R.P., and Little, T.E.: "Constrained Residual Acceleration of Conjugate Residual Methods", paper SPE 13536 presented at the Eighth SPE Symposium on Reservoir Simulation, Dallas (1985).

6. Meter, D.M. and Bird, R.B., "Tube Flow of Non-Newtonian Polymer Solutions: Part I Laminar Flow and Rheological Models", AICHE Journal, Vol. 10, No. 6, Nov. 1964, p. 1143-1150.

7. Hong, C., "Development of a 2-D Micellar/Polymer Simulator", PhD. Dissertation, The University of Texas at Austin, 1982.

8. Hirasaki, G.J., "Ion Exchange with Clays in the Presence of Surfactant", Soc. Pet. Eng. J. (April 1982), p. 181-192.

9. Modine, A.D., Coats,K.H., and Wells, M.W., "A Superposition Method for representing Wellbore Crossflow in Reservoir Simulation," SPE 20746 presented at the 65th Annual Technical Conference and Exhibition of the Society of Petroleum Engineers, New Orleans (1990).

10. Young, L.C., "Equation of State Compositional Modeling on Vector Processors", SPE paper 16023 presented at the Ninth SPE Symposium on Reservoir Simulation, San Antonio, Texas, February 1-4, 1987.

11. Peng, D.Y., and Robinson, D.B., "A New Two-Constant Equation of State", I and E.C. Fundamentals (1976) 15, No. 1, pp. 59-64.

12. Redlich, O., and Kwong, J.N.S., "On the Termodynamics of Solutions V. - An Equation of State Fugacities of Gaseous Solutions", Chemical Review (1949) Vol. 44, pp.52-63.

5000.4.4 -653


13. Odeh, A.S., “An Equation for Calculating Skin Factor Due to Restricted Entry”, JPT, June 1980, pp. 964 - 965.

-654 5000.4.4

Keyword
Index
v

000000Keyword Index

AA 3-209, 4-332ABORT 3-209, 7-444ABSRES 7-442ABSTOL 7-442ACC 8-463ACPGCR 10-510, 10-514, 10-554ACQ 12-616ACTION 5-356ACTIVATE 13-625ACTIVE 6-410ADD 4-309, 4-321, 6-383, 8-474ADDNGL 3-114ADJFPERF 11-611ADJSPN 11-611ADJTOL 7-451, 13-629ADJTUBING 11-611ADJWI 11-611ADJWLFL 11-611ADP1 9-486ADP2 9-486AFTER 3-216ALABEL 3-209ALL 2-65, 2-66, 3-115, 3-187, 3-209, 4-227, 4-

242, 4-244, 4-252, 4-310, 4-311, 4-321, 5-349, 5-351, 5-356, 6-397, 6-410, 6-416, 6-417, 7-445, 10-520, 10-562

ALLCOMP 6-396ALLWELLS 4-227ALLWLS 4-296ALQ 3-169, 3-177ALSOCHILDREN 6-384ANGLA 3-90ANGLE 10-506, 10-510ANGLV 3-90ANISO 14-639

ANSARI 10-511, 10-516ANSBEG 10-512, 10-516AP1 9-486AP2 9-486AP3 9-486APPEND 4-311, 4-315ARCMP 6-387AREA 2-65, 2-66, 3-118, 3-198, 3-209, 3-216,

3-217, 3-220, 4-225, 4-227, 4-228, 4-232, 4-235, 4-238, 4-239, 4-242, 4-243, 4-245, 4-246, 4-248, 4-249, 4-251, 4-253, 4-254, 4-256, 4-259, 4-269, 4-270, 4-271, 4-272, 4-288, 4-289, 4-295, 4-300, 4-301, 4-306, 4-309, 4-311, 4-313, 4-316, 4-318, 4-320, 4-323, 4-326, 4-328, 4-330, 4-333, 5-343, 5-347, 5-349, 5-353, 5-355, 5-356, 5-357, 5-362, 5-364, 5-366, 6-401, 10-527

ARLYR 6-387ARRAYS 6-386ARTLFT 5-348ASF 12-621ATWAG 3-184, 3-185ATWGCL 3-190ATWGCT 3-191ATWGVA 3-189AUTO 3-194, 4-311AUTOCYCLE 2-74AVG 4-233, 5-356, 5-357AVGGOR 4-233AVGLOR 4-233AVGWCT 4-234AVGWOR 4-233AZIZ 3-205, 10-515

BB 4-332BATCH 7-457, 7-458BEGGS 3-100, 3-205, 10-511, 10-515BENEFIT 5-356, 5-357

5000.4.4 KI-655


BETAP 9-490BHITAB 3-175, 10-547BHLTAB 10-523BHP 3-112, 3-159, 5-368, 7-445BHP(IQ) 10-548BHP(IQI) 3-175BHP(ITHP) 3-169, 3-175BHPADD 3-177BHPI 3-209BHPITN 3-166BHPP 3-209BHPTAB 3-169, 10-523BHPWAG 3-202BHTEMP 10-536BHVTAB 10-523BINARY 2-69, 6-412, 6-413BLITZ 7-449BOTH 7-434, 13-626BOUNDARY 14-639BP 9-486BRK 9-486BUILDUP 6-390

CC 1-48, 4-332CAINJ 9-492CATEGORY 5-356CBHPMN 7-445CBLGRID 13-630CBLITZ 13-628CCNDN 2-66CENTER 14-639CHKTAB 7-445CINJ 3-209CLINJ 9-491CLOSE 4-305, 10-520CNDBNK 3-218CNDBWL 3-219, 3-220CNDN 2-66CNVFAIL 6-380CNVFLOFF 6-380COMP 3-105, 3-107COMPERF 3-204CON 3-193CONDENSATE 4-335CONTRACT 12-616CONTROL 10-519CORERST 2-58CP 9-484

CPADS 9-484CPERF 3-215CPINJ 9-491CPLOT 2-66CPROD 3-209CPUWMG 6-380CRK 9-486CROSS 6-413CSE1 9-490CSEP 9-490CSTART 3-216CSTOP 3-217CUMTOL 12-616CURVE ELEVPR 10-506CURVE IDPR 10-508CURVE IPVTPR 10-509CURVE TEMPPR 10-504CURVE TMGRPR 10-505CURVE VCPR 10-507CUTOFF 5-356CYCLE 3-209CYCLETABLE 3-209CYCLIC 3-214

DD 4-332DAMP 2-63DATE 2-74, 2-77DATUM 6-410DAYS 4-231, 4-322, 5-345DBOT 3-86DCQ 12-616DCQANT 12-616DCQCON 12-616DCQLIM 12-616DDIAM 11-604, 11-605, 11-611DEACTIVATE 13-625DECLASS 5-364DEF 6-397DELETE 6-383DELTAP 4-280DENS 10-543DENSITY 3-183DEPI 3-209DEPP 3-209DEPTH 10-505, 10-514DHCOR 10-510DHTOP 3-87DIAM 3-90, 3-183, 3-204

KI-656 5000.4.4


DIAMETER 10-510, 10-514DIFFUSION 8-482DIM 2-58, 9-483, 10-571, 14-638DISSOL 10-536DIST 4-260DIV 8-474DJKSEP 3-103DKH 11-604, 11-611DKRG 11-604, 11-611DKRW 11-604, 11-611DLENGTH 11-604, 11-605, 11-611DLIQ 3-105, 3-107DOBJMN 10-573DOBJND 10-574DPBHMX 3-162, 3-195DPRGR 11-604, 11-605, 11-611DRILL 4-315DRILLQUEUE 4-310DRILLWELL 4-315DRLRIG 4-309DRLTRG 4-313DROUGH 11-604, 11-605, 11-611DRYTRG 3-114DSGR 11-604, 11-611DSWR 11-604, 11-611DT 7-434, 9-496DTCUTF 7-446DTMPL 13-626DTONLY 7-434, 13-626DTOP 3-86DTPWM 5-350DTQMAX 7-436DTSOAK 3-209DTWAG 3-203DUKEAT 10-511DUKLER 10-511DUNROS 3-205, 10-515DWI 11-604

EE 4-332ECOLIM 3-136EDGE 3-187EFF 5-369, 5-370EFFSCL 4-303EFFTAB 5-370ELEVPR 10-510, 10-514END 2-78ENDASF 12-621

ENDCATEGORY 5-356ENDCBLGRID 13-630ENDDRILLWELL 4-315ENDGFO 12-616ENDIMPGRID 13-624ENDINC 1-49ENDPOINT 3-122, 3-124, 3-125ENDSEP 3-103ENDSTEP 5-356, 5-357ENDTUNING 11-600ENDWINDOW 6-383EPHIP 9-489EQ 8-474EQUIL 8-479ESALT 9-484EST 8-464ETRGOP 4-252EXCEL 7-448EXCLUDE 5-356EXPONENT 3-149

FFACFIL 6-388FACUTL 6-388FASTSIM 7-454FGRBGN 5-369FGRINC 5-369FIELD 2-65, 2-66, 3-118, 3-198, 3-209, 3-216,

3-217, 3-220, 4-227, 4-228, 4-232, 4-235, 4-238, 4-239, 4-242, 4-244, 4-245, 4-246, 4-248, 4-249, 4-251, 4-252, 4-253, 4-254, 4-256, 4-259, 4-269, 4-270, 4-271, 4-272, 4-280, 4-286, 4-288, 4-295, 4-300, 4-301, 4-306, 4-309, 4-311, 4-313, 4-316, 4-318, 4-320, 4-323, 4-326, 4-328, 4-330, 4-333, 5-343, 5-347, 5-349, 5-353, 5-355, 5-356, 5-357, 5-362, 5-364, 5-366, 6-386, 6-401, 10-527

FILE 7-457FILENUMBER 10-566FIXGL 5-369FLASH 8-463FLDCMP 6-387FLLYR 6-387FLOANG 3-158FLOSTA 2-65, 2-66, 3-118, 3-198, 3-209, 3-

216, 3-217, 3-220, 4-225, 4-227, 4-228, 4-232, 4-235, 4-238, 4-239, 4-242, 4-

5000.4.4 KI-657


243, 4-245, 4-246, 4-248, 4-249, 4-251, 4-253, 4-254, 4-256, 4-259, 4-269, 4-270, 4-271, 4-272, 4-288, 4-289, 4-295, 4-299, 4-301, 4-306, 4-309, 4-311, 4-313, 4-316, 4-318, 4-320, 4-323, 4-326, 4-328, 4-329, 4-333, 5-343, 5-347, 5-349, 5-353, 5-355, 5-356, 5-357, 5-362, 5-364, 5-366, 6-401, 10-527

FLOW 10-520, 14-641FLOWIN 7-439FLOWVEC 2-71FLPOT 6-387FLUX 6-388FM 3-97FORM 2-65, 2-66, 2-69, 6-412, 6-413FPERF 3-83, 9-493, 10-545, 13-632FPO 4-248FPROD 4-245, 4-246, 4-248, 4-250FREQUENCY 3-149FRES 3-117, 3-198, 3-209, 4-288FRESN 4-288FRG 10-526FRGFO 10-526FRLOSS 10-554FRO 10-526FROM 3-128FRONT 14-638FRPGCR 10-510, 10-514, 10-554FRW 10-526FSALES 4-250FSCMP 6-387FSLYR 6-387FSTD 3-117, 3-198, 3-209, 4-288FTRANF 8-477FTRANS 8-476, 13-634FTWMIX 4-338FVEG 3-89FVEGF 3-97FVEW 3-89FVEWF 3-97FXFORM 6-413

GG 3-115, 3-117, 3-136, 3-175, 3-209, 4-228, 4-

232, 4-237, 4-239, 4-242, 4-244, 4-288, 4-289, 5-343, 5-349, 5-357, 10-547, 14-639

GAMHF 9-487GAMMAC 9-487

GAS 4-235, 5-368, 8-481, 10-520, 10-541, 10-572, 11-609

GASCOND 4-260GASFUL 4-246GASINJ 4-312GASLIF 10-554GASLIFT 10-566GASMAX 3-195GASMIN 3-195GASMKP 4-249GASPERC 8-466GASPLANT 3-110GASPROD 4-312GASRATE 3-169GASRMON 8-466GASSKG 4-245GASSLS 4-248GASSPM 10-526GASTHP 3-179GASWAT 4-235GASWELL 3-188GATHER 2-65, 2-66, 3-118, 3-198, 3-209, 3-

216, 3-217, 3-220, 4-225, 4-227, 4-228, 4-232, 4-235, 4-238, 4-239, 4-242, 4-243, 4-245, 4-246, 4-248, 4-249, 4-251, 4-253, 4-254, 4-256, 4-259, 4-269, 4-270, 4-271, 4-272, 4-288, 4-289, 4-295, 4-299, 4-301, 4-306, 4-309, 4-311, 4-313, 4-316, 4-318, 4-320, 4-323, 4-326, 4-328, 4-329, 4-333, 4-336, 5-341, 5-343, 5-347, 5-349, 5-353, 5-355, 5-356, 5-357, 5-362, 5-363, 5-366, 6-402, 10-527

GAUSS 7-448GCCMP 6-387GCLYR 6-387GE 8-470GEL 9-493GFIRST 3-198GFO 12-616GIBBS 8-461GIBOFF 8-463GINJ 4-314GINJMOB 3-124GINJOP 4-273GLAST 3-198GLDAMP 4-303GLEFMN 4-302GLGMAX 4-299GLGMIN 4-300GLGOP 4-305GLIMIT 3-133

KI-658 5000.4.4


GLR 3-169, 4-297, 11-601GLR(IQ) 10-548GLRADD 4-301GLRM 5-356GLRMAX 3-195, 4-303GLRMIN 4-303GLRTAB 4-297GLRTBP 4-298GLVDZ 10-536GOR 3-138, 3-169, 4-233, 4-297, 10-566, 11-

601GOR(IQ) 10-549GORCON 3-149GORLIM 3-149GORM 5-356GORMAX 3-195GORPEN 3-148GPMIN 4-325GPROD 4-314GRAD 3-90GRATE 4-233, 11-600GRATIO 3-173GRID 3-80, 3-85, 3-98, 8-469, 8-471, 8-472, 8-

475, 9-487, 9-497, 13-632, 13-634, 13-635

GRIDBLOCK 6-410GRIFFI 3-205GRIFFITH 10-515GROUP 4-310, 4-330, 4-331GRPGCR 10-510, 10-514, 10-554GSMIN 4-325GTHPWL 3-179GURTR 4-289GURTS 4-289

HH 3-86, 3-204HAG-BEG 10-516HAGEDO 3-205HAGEDORN 10-515HBOT 3-87HCPVTS 6-380HEADER 6-401, 10-560HEATTR 10-554HISTSYS 5-346HITLIST 4-303HTC 10-510, 10-514HTCPIPE 10-554HTCTUB 10-554

HTOP 3-87HTOT 3-87HTOUTPUT 10-566

IIALQ 3-169IBAT 3-80, 10-522, 10-526ICMT 3-88ICMTF 3-96ID 10-508IDPR 10-519IGC 3-80IGLR 3-169IGNORE 10-553IGOR 3-169IMPES 2-65, 13-624IMPGRID 13-624IMPLICIT 2-64, 13-624IMPSTAB 7-439IMPTHP 3-161IMPWEL 7-453INCLUDE 1-48, 10-553INCR 4-314INFLUX 4-279INITSLUG 3-198INJ 3-117, 4-227INJA 3-124INJGR 4-289INJMIN 4-243INJREG 4-239, 4-274, 4-280, 4-286, 4-311, 4-

313, 4-316INJREGN 4-278, 13-634INJRGR 4-277INJRNM 4-276INJTAR 4-287INNER 3-187INPLACE 6-393INSTANT 12-616INTERACTIVE 7-457INTERVALS 3-179INVK 3-193INVKH 3-193IOGR 3-169IONEX 9-489IPLABEL 3-209IPRES 3-180, 4-297, 10-543, 10-547IPRTSS 6-400IPUMP 4-290IPVT 10-509, 10-532

5000.4.4 KI-659


IPVTOC 10-536IPVTTB 10-536IPVTW 10-522, 10-532IPVTWC 10-536IPVTWT 10-536IQEWS 3-169IQGAS 3-169IQI 3-175IQLIQ 3-169, 4-297IQO 3-169, 4-297IRDIST 4-279IRGAS 4-282IRPCTA 4-278IRSRCW 4-276ISAT 3-88ISATF 3-96ISATI 3-88ISATIF 3-96ISO 14-639ITARG 4-239ITEMP 3-180, 10-543ITER 6-385, 7-448, 7-449, 13-628ITERL 6-385ITHP 3-175ITNGLG 4-308ITNGRE 3-127ITNLIM 7-437ITNMPL 13-627ITNSTP 3-125ITNSTQ 3-126ITNTHP 3-162ITNWIMULT 3-222ITOP 3-209ITUBE 3-168IW 3-80, 3-85, 3-98IWCUT 3-169, 4-297IWGR 3-169IWIM 3-88IWIMF 3-96

JJCOR 7-450JCPR 7-450, 13-629JGAUS 7-451JLU1 7-449JLUN 7-449JOPT1 7-451JOPTN 7-450JW 3-80, 3-86, 3-98

KK 3-86, 3-204KAC 8-464KAC2 8-464KEYCMP 3-110, 3-118, 3-198, 4-261, 4-264, 4-

267KG 14-639KH 3-86, 3-204KHWI 3-90KMAX 8-464KMAX2 8-464KVALUE 14-639KVALUES 3-105, 3-107KW 14-639

LL 3-85, 3-98, 4-228, 4-232, 10-547LAST 2-75, 4-256LCDOFF 6-382LCDON 6-381LDEST 3-101, 3-105, 3-107LE 8-470LEN 3-204LENGTH 3-90, 3-179, 10-504, 10-506, 10-510,

10-514LFRAC 3-101, 3-105, 3-107LFTGAS 4-228, 5-343LFTWLS 4-296LGR 3-132LGRMAX 3-179, 3-195LIFT 5-341LIFTEFF 4-303LIFTONLY 5-356LIFTREQ 5-356LIMIT 3-132, 3-133LINK 10-522, 10-532, 10-536, 10-537LIQPROD 4-312LIQUID 3-115, 3-136, 3-187, 3-209, 4-235, 4-

237, 5-368, 10-520LIST 1-49LKCPLD 2-73LOCK 10-572LPGFED 4-271LPGOUT 4-272LPGPLANT 4-267LPROD 4-314LSCALE 4-240

KI-660 5000.4.4


MMAP 2-69, 2-70MAPOUT 6-374, 9-494MAPWT 6-396MAPX 6-395MAPXT 6-395MAPY 6-395MAPYT 6-395MAPZ 6-395MAPZT 6-395MAX 7-442MAXCYC 12-616MAXFLI 10-554MAXGLR 4-316MAXGOR 4-316, 4-325MAXNIT 10-554MAXOGR 4-316MAXONLY 7-434, 13-626MAXOVR 7-440MAXPRD 10-519MAXQG 4-316MAXQGI 4-316MAXQLIQ 4-316MAXQO 4-316MAXQW 4-316MAXQWI 4-316MAXRER 11-602MAXRNE 11-602MAXSCALE 4-303MAXSSI 10-554MAXVEL 10-574, 10-576MAXWCUT 4-316, 4-325MAXWGR 4-316MAXWOR 4-316MBAWG 3-164MEQ/ML 9-490MGOR 5-340, 6-388MI 3-118MIMKP 4-251MINGOR 4-325MINQG 4-316, 4-325MINQGI 4-316MINQLIQ 4-316MINQO 4-316, 4-325MINQW 4-316, 4-325MINQWI 4-316MINRER 11-607MINWCUT 4-325MIPLANT 4-264

MITAG 3-190MNFLCF 11-605MNPFCF 11-605MOBAVB 3-165MOBAVG 3-165MOBILITY 3-144, 3-145MODEL 10-519MODLAND 8-468MOLES 3-116, 3-209MONTH 12-616, 12-621MONTHS 4-231, 4-322, 5-345MULT 4-227, 4-314, 8-474MULTFL 8-478MULTIR 8-478MULTRT 3-115MUSTFLOW 5-356, 5-364, 5-365MUSTLIFT 5-356MWL 3-105, 3-107MXDTCF 7-446MXDTFC 7-446MXLSPN 10-571

NN 3-80NAMAX 2-58NAME 3-80, 10-510, 10-514, 10-519, 10-526NAMES 14-639NAREAX 2-58NBATMX 2-58NBEPS 13-629NBHIMX 2-58NBHIQ 2-59NBHIV 2-59NBHPMX 2-59NBHPQ 2-59NBHPV 2-59NCOL 1-50NCPDIM 9-483NCPLMX 2-59NCPMAX 9-483NCYCLES 10-573NCYCMX 2-59NCYCTM 2-59NESMAX 9-483NETPAR 10-554NEW 4-310, 4-315, 5-340NEWBHPTAB 3-173NEWSEP 3-112NEWWEL 11-589, 11-590

5000.4.4 KI-661


NEXTONLY 5-351NFSMAX 2-59NGCMAX 2-59NGLFED 4-269NGLOUT 4-270NGLPLANT 4-261NGLRMX 2-59NGLRQ 2-59NGLRV 2-59NHARM 13-629NIADD 2-59NIRMX 2-60NIT 7-449, 13-628NITG 13-628, 13-630NKEY 3-110, 4-261, 4-264, 4-267NN 10-510, 10-514, 10-519, 10-526, 10-574NO 4-315, 10-529, 10-573, 10-574, 12-616NOCASCADE 13-634NOCONVERT 8-469, 8-471, 8-472, 8-475, 9-

497, 13-635NOCPRS 11-589, 11-590NOCUTS 7-439NODCON 10-532NODE 6-402, 10-532, 10-560, 10-562NODES 10-526, 10-541, 10-559, 10-566, 10-

574NODIST 4-274NODSOURCE 10-541NOFLOW 14-641NOFRICTION 3-100NOHYSW 3-83NOITER 7-448, 7-449, 13-628NOLFTGAS 4-229, 5-344NOLIFTREQ 5-356NOLIST 1-49NONE 4-252, 6-374, 7-434, 7-445, 13-626NONPWM 5-348NOOUT 2-74NOPINT 13-625NOPRTI 9-484NOPSAT 8-464NOPTG 13-628, 13-630NOPWDEP 3-83NORESET 3-83, 3-154, 3-155, 3-156NORIGS 4-311NORMAL 10-552NORTH 7-449, 13-628NOSHUTIN 3-194NOSKIP 1-50NOSLIP 3-205, 10-511, 10-515NOVDB 2-70NOWELL 4-335

NPMPMX 2-60NPMPV 2-60NPRFMS 2-60NPRFMX 2-60NPRFSOL 2-60NPRFTOT 2-60NPRIMX 2-60NPROMX 2-60NPRSYS 2-60NPRTM 14-638NPTNMX 2-60NPWMAL 2-60NPWMPA 2-60NPWMPM 2-61NPWMPS 2-61NRCMUN 2-61NRIGMX 2-61NRIGTOT 2-61NSLUG 9-483NSTGMX 2-61NTHGMX 2-61NTHPGQ 2-61NTHPGV 2-61NTOPTC 10-573NTRCEM 14-638NTRWLM 14-638NWIMV 2-61NWMAX 2-61NWRKG1 2-61NWRKG2 2-61NWSWT 10-573, 10-574NX 6-384, 8-469, 8-471, 8-472, 8-475, 9-497,

13-635NXFCON 2-61NXFWEL 2-62NY 6-384, 8-469, 8-471, 8-472, 8-475, 9-497,

13-635NYEARS 12-616NZ 6-384, 8-469, 8-471, 8-472, 8-475, 9-497,

13-635

OO 3-115, 3-136, 3-209, 4-228, 4-232, 4-237, 4-

242, 5-343, 5-349, 5-357, 10-547, 14-639

OBJCOEF 10-571OFF 2-72, 2-73, 3-100, 3-161, 3-164, 3-184, 3-

185, 3-188, 3-220, 4-230, 4-240, 4-259, 4-282, 4-285, 4-288, 4-303, 4-311, 5-

KI-662 5000.4.4


351, 5-365, 5-367, 5-369, 6-389, 6-391, 6-393, 6-394, 6-396, 6-399, 6-413, 6-416, 6-417, 7-438, 7-439, 7-452, 7-453, 8-466, 8-468, 8-482, 10-530, 10-562, 10-573, 10-577, 14-643, 14-644, 14-645

OGR 3-169, 10-566OGR(IQ) 10-549OIL 4-235, 5-368, 8-481, 10-520, 10-541, 10-

572, 11-609OILMIN 3-195OILPROD 4-312OLDINJ 3-123OMEGAS 3-103OMEGBS 3-103ON 2-73, 3-100, 3-161, 3-164, 3-184, 3-188, 3-

220, 4-230, 4-240, 4-259, 4-282, 4-285, 4-303, 5-365, 5-367, 5-369, 6-396, 6-399, 6-413, 6-416, 6-417, 7-439, 7-452, 7-453, 8-466, 8-468, 8-482, 10-530, 10-562, 10-572, 10-576

ONLY 4-242, 4-244ONLYCHILDREN 6-384ONTIME 3-146, 4-226OPEN 3-194, 4-305, 10-520OPMIN 4-325OPROD 4-314OPRSYS 4-336OPTMBL 2-63OPTTAB 4-295ORDER 6-417ORDEROFF 6-417ORIGIN 14-639ORKISZ 3-205ORKISZEWSKI 10-515OUTCNi 10-533, 10-537OUTCNT 10-532, 10-536OUTCON 10-532, 10-536OUTCTi 10-533, 10-538OUTFIL 10-554OUTFILE 4-303OUTITR 10-554OUTNDi 10-533, 10-538OUTNOD 10-532, 10-536OUTPAVG 6-410OUTPUT 6-374, 9-494OUTRFT 6-400OUTSEP 6-397OUTWINDOW 6-383OUTWT 6-396OUTX 6-395OUTXT 6-395

OUTY 6-395OUTYT 6-395OUTZ 6-395OUTZT 6-395OVER 8-469, 8-471, 9-497, 13-635

PP 3-166, 14-639PAFACT 5-356, 5-357PASS 5-356, 5-357PATNCI 3-185PATNPP 3-187PATTERN 3-88, 6-410PATTN 3-184PCCD 6-381PCDOFF 6-381PCDON 6-381PCTFQ 3-190PCTMI 3-190PCTMN 3-190PDCORR 10-510, 10-514PERFPT 3-99PERKINS 10-519PERM 9-484PFIRST 3-209PFMCRV 4-296, 4-303PGRAD 4-280PHASE 5-357PHASID 8-481PI 3-155PIAGL 3-189PILABEL 3-209PINJ 3-120, 3-209PIPE 10-523, 10-532, 10-536, 10-537PIPES 10-510PIVOL 3-189PJACO 2-63PLANT 4-246, 4-248, 4-259PLNTRY 3-110, 4-261, 4-264, 4-267PLOT 2-65, 2-70PLOTLIST 6-415PLOTPTN 6-399PLUG 3-132, 3-133, 3-135PLUGPLUS 3-132, 3-133PLUS 2-70, 2-76, 3-138, 4-261, 4-264, 4-267PMAX 10-574, 10-575PMAXI 10-526PMFACT 5-356, 5-357PMIN 10-526

5000.4.4 KI-663


PMPTAB 4-291POLYF 9-486POLYMER 9-484POLYT 9-484POR 9-484POTENTIAL 4-310POWN 9-487PP 3-192PPM 9-490PPOPT 10-530PRADJFPERF 11-602PRDEBUG 11-602PRDMIN 4-242PREDICT 5-340PRES 3-101, 10-547PRESIN 10-510, 10-514, 10-554PRESSURE 3-144, 3-145, 3-180, 4-297, 10-

543, 10-566PRESUP 10-520PRFLIM 3-138PRFPER 11-602PRFRPT 6-380PRFSTAT 3-98PRIIR 4-286PRINT 6-385, 9-493, 9-494, 14-645PRINTOUT 6-399PRIOP 4-285PRMEXP 4-279PRMGOR 5-369PRNDRP 11-601PROD 3-115, 3-141, 4-227, 4-253, 4-254PROFILE 12-616PROJNM 4-285PROJWL 4-286PROPTN 4-275PRRTOL 10-554PRSDLT 5-367PRSYS 5-347, 5-356, 5-357, 10-526PRTR 9-484PRTSWT 10-576PRTUBSPN 11-602PRWI 6-412PRWLRP 11-601PRWSTA 6-412PS 10-554PSAT 8-464PSEUPRES 10-551PSEUTAB 10-550PSEUWS 10-552PSEUXY 10-551PSLUG 9-492PTARG 4-228, 5-342, 10-526

PTARGH 4-230PTGFRQ 4-231PTHLD 8-479PTNGOR 3-189PTOI 3-209PTOL 7-450PVDEF 2-72PVT 7-445PVTTABLE 3-101PWDEP 3-90PWMCAT 5-364PWMDBG 5-351PWMFILE 5-351PWMFRQ 5-345PWMGC 5-341PWMOBN 5-350PWMSTEP 5-356, 5-357PWMTLP 5-348PWMTRG 5-367PWMWCN 5-368PWMWPA 5-362PWMWPM 5-363

QQEWS 3-169QG 10-526, 10-574QGAS 3-169, 10-566QGMIN 5-354, 10-526, 10-574, 10-575QI 3-175, 10-547QL 10-526QLIFT 4-293, 10-547QLIFTA 4-295QLIFTM 4-306QLIQ 3-169, 4-297, 10-566QMAKE 4-250, 4-251QMAX 3-131, 4-315QMAXGR 6-415QMAXI 3-209QMAXP 3-209QMAXWG 3-201QMIN 3-139QMULT 3-140QMX 3-163QO 3-169, 4-297, 10-526, 10-566, 10-574QOMIN 5-353, 10-526, 10-574, 10-575QOMINL 5-365, 5-366QPMP 4-291QPOOL 4-250QRATE 4-245, 4-246, 4-269, 4-270, 4-271, 4-

KI-664 5000.4.4


272QSALES 4-248QSTMX 3-150QUAL 3-120, 3-209QUEUE 4-317QV 9-489QW 10-526

RRADB 3-89RADBP 9-493RADW 3-90RADWP 9-493RATE 3-144, 3-145, 3-173, 4-314RCCD 6-381RCDOFF 6-381RCDON 6-381RCMPOR 3-197RCMPPERF 3-194RCMPUNT 3-86, 3-194RCMRPT 6-381RDFAC 12-616RECFAC 4-258REDIST 4-274REGBLK 6-385REGBOG 6-386REGCMP 6-387REGION 2-65, 2-66, 6-402REGIONS 6-385REGOG 6-385REGSEP 6-398REINJ 10-526REINJCOMP 3-130RELERR 11-601RELRES 7-443RELTOL 7-442REMOVE 5-356, 5-357, 10-526REPLACE 4-309, 4-321RES 3-116, 3-117, 3-198, 3-209, 8-463RESETCUM 3-223RESTART 2-74RESTOT 3-221RESWAT 3-221RFLOW 3-156RFRPRS 4-280RFT 6-387RFTFILE 6-388RG 3-192RGCAVG 11-589, 11-590

RGCAVL 11-589, 11-590RGCAVO 11-589, 11-590RGCAVR 11-589, 11-590RGCAVW 11-589, 11-590RIGS 4-315RINJOP 4-274RK 9-484RKHKV 3-90RKMULT 9-494RNP 11-601ROM 3-218ROUGH 3-90, 3-204ROUGHNESS 10-510, 10-514RRES 4-288RSTD 4-288RTHP 11-601RTOL 7-449, 13-629RTOLG 13-629, 13-630RTRTOL 10-554RUN 2-57RUNID 6-401

SSATDEBUG 6-419SCALE 4-233, 5-356, 5-357SEGREG 2-73SEP 6-386SEPARATOR 3-101, 3-105, 3-107SEPS 6-386SET 10-507, 10-508SGL 3-88SGLF 3-96SGMN 3-88SGMNF 3-96SGMX 3-88SGMXF 3-96SGRO 3-88SGROF 3-96SHCGAS 10-554SHCOIL 10-554SHCWAT 10-554SHEAR 9-487SHFTOG 6-379SHFTW 6-379SHUT 3-195, 5-357SHUTIN 3-132, 3-133, 3-135, 3-194, 3-198SHUTPF 11-589, 11-590SIM 6-388SIMPL 10-573

5000.4.4 KI-665


SKIN 3-89, 3-204SKIP 1-50SLABELS 3-209SLEEP 7-457SLIMIT 3-135SLVCUT 7-452SOR 3-135, 3-138SORMAX 3-196SOUCOM 10-542SPFCT 10-532, 10-536SPFCTi 10-533, 10-538SPNPTU 10-545SPNPVT 10-544SPNPVW 10-543SPREADSHEET 10-566SPRLIST 6-417, 10-562SS 8-464SSLOPE 9-486SSSID 6-401SSSUM 6-388, 6-401, 10-560SSSUMR 6-388STAGE 3-101, 3-105, 3-107START 2-76STAT 3-89, 3-98STATUS 3-194, 10-519STBCHK 2-63STD 3-116, 3-117, 3-192, 3-198, 3-209, 4-273,

4-274, 6-410STEPNO 2-74STMMAX 3-196STOP 2-77, 5-350, 5-357STORAGE 2-58SUB 8-474SUBTRACT 4-309, 4-321SUM 7-442SUNITS 9-490SURF 8-463SURFACE 2-65SURFTEMP 3-179SVLGAS 10-555SVLOIL 10-555SVLWAT 10-555SWING 12-616SWL 3-87SWLF 3-95SWMN 3-87SWMNF 3-95SWMX 3-87SWMXF 3-96SWRO 3-87SWROF 3-96SYSSEP 5-369

SYSTB 5-345SYSTEM 5-341

TTAB 6-401, 10-560TABGLE 4-295TABLE 3-196, 10-552TABSCL 4-296TABWC 4-296TAKE 12-616TARGET 10-519TARGETS 4-310TBADJ 11-590TBHP 11-609TCBHP 11-601TCUT 7-438TEMP 3-101, 3-180, 10-504, 10-505, 10-509,

10-526, 10-543TEMPDW 10-510, 10-514, 10-519TEMPPR 10-510, 10-514TEMPUP 10-510, 10-514, 10-519TERC 11-609TEST 3-144TESTGL 4-302TFORM 6-412TFPERF 11-604THICKNESS 10-510, 10-514THP 3-112, 3-160, 3-169, 3-175, 4-291, 5-342THP(IQ) 10-548THPGTB 3-180THTEMP 10-536, 10-538TIME 1-47, 2-74, 2-76, 4-305, 5-351, 6-388, 6-

391, 6-393, 6-394, 14-643, 14-644, 14-645

TIMEIN 10-554TIMEST 10-554TINJ 3-119, 3-209TINJWAG 3-203TITLE1 2-75TITLE2 2-75TITLE3 2-75TMGRPR 10-510, 10-514TNET 10-554TNEXT 4-305, 5-351, 6-389, 6-391, 6-393, 6-

394, 14-643, 14-644, 14-645TO 3-128TOLCMC 10-554TOLCP 10-554TOLD 7-441

KI-666 5000.4.4


TOLEX 7-451, 13-630TOLMN 7-451, 13-629TOLMX 7-451, 13-629TOLR 7-442TOLRKV 10-554TOLRPC 10-554TOLRSP 10-554TOLRTC 10-554TOLSCN 7-443TOLST 7-451, 13-630TOLWCN 7-444TOTAL 3-122, 3-124, 3-125, 5-343, 5-349, 5-

357, 11-590TOTGAS 4-303TPRND 11-609TRACER 14-639, 14-645TRACIN 14-642TRACK 4-335, 6-388TRACKW 6-388TRAP 3-218TRCKOF 4-335TRCOFF 14-639TRGOPT 4-232TRGORD 4-235TRGPRS 4-280TRGPWM 5-348TRGQMN 4-237TRGTOL 4-238TRKTOL 4-335TS 10-554TSFM 3-114TSPN 11-605TSSDAT 6-380TSSMFG 6-380TSSUM 6-379, 6-388TSSUMG 6-379TSTEPS 4-231, 4-322, 5-345TSTPRF 3-137TTHP 11-609TTUBING 11-604TUBCNT 10-536TUBCON 10-536TUBE 3-182TUBID 10-519TUBING 10-514, 10-523, 10-532, 10-536, 10-

537, 10-563TUNING 11-600TWELL 11-604TWLFL 11-604TYPE 10-519TYPPRS 4-279TYPVDG 4-279

UUNIFORM 4-273, 4-275UNIT 3-86, 3-98

VV98 7-439VALSET 10-520VALVE 10-523, 10-532, 10-536, 10-537VALVEC 10-519VALVES 10-519VC 10-507VCPR 10-519VDB 2-70VDEST 3-101, 3-105, 3-107VDGFCT 4-279VEL 5-343VELRST 10-574VELWCU 10-574VELWCUT 10-576VENT 4-260VFRAC 3-101, 3-105, 3-107VIS 10-543VISC 3-180VISCOSITY 3-183VOID 4-289VOIN 4-289VOLBAL 2-64, 3-165VOVER 8-472, 8-475, 9-497, 13-635VP0 9-484VSHFTS 3-103

WW 3-115, 3-117, 3-136, 3-175, 3-209, 4-228, 4-

232, 4-237, 4-239, 4-242, 4-244, 4-288, 4-289, 5-343, 5-349, 5-356, 5-357, 10-547, 14-639

WAG 3-185, 3-198WAGPERF 3-188WARN 5-350, 5-357WARNING 4-303WATER 4-235, 5-368, 10-541, 10-572, 11-609WATINJ 4-312WATPROD 4-312WBGRAD 3-165

5000.4.4 KI-667


WCPLOT 6-391WCTMAX 3-195WCUT 3-138, 3-169, 3-221, 4-233, 4-297, 5-

356, 5-370, 10-566, 11-601WCUT(IQ) 10-549WCUTLM 5-369WDAT 10-536WDL 3-89WDLF 3-97WDNDG 3-193WDZ 10-536WELCMP 6-387WELCON 10-536, 10-575, 11-605, 11-611WELHEAD 10-536WELL 2-65, 2-66, 3-80, 3-83, 3-98, 3-146, 3-

194, 3-216, 3-217, 3-219, 4-289, 4-299, 4-300, 4-315, 4-318, 4-323, 4-325, 4-328, 4-329, 4-330, 4-331, 4-332, 5-346, 5-353, 5-354, 5-362, 5-363, 5-365, 6-402, 6-415, 6-417, 10-536, 10-545, 10-575, 11-602, 11-604, 11-611, 13-632

WELLS 6-385, 10-566WELRPT 6-380WFILE 6-391WFLUX 6-391WGLRMIN 4-303WGPCMP 6-387WGR 3-169, 10-566, 11-601WGR(IQ) 10-549WI 3-154WIADJ 11-589WIL 3-89WIMULT 3-221WIMULTAB 3-221WIMUWL 3-221WINJ 4-314WINJMOB 3-122, 3-125WINJT 4-338WKHMULT 3-147WLASTR 6-393WLDRTIME 4-318WLGRP 6-386, 6-414, 10-559, 10-563WLHIS 6-386WLIMIT 3-132WLLCMP 6-387WLLYR 2-65, 2-66, 6-386, 6-415WLLYRS 6-386WLPOT 6-387WLSUM 6-388WLTYCH 3-128WLVEL 10-576WLWDAT 3-159

WMAN 5-350WMAP 6-391WMAPOLD 6-391WMGL 5-356, 5-357WMITN 5-340, 10-578WML 10-526WMN 10-526WNDGDV 3-192WPLOT 6-391WPMIN 4-325WPROD 4-314WPWMDB 5-371WRATE 4-233, 11-601WRATIO 3-173WREST 6-391WRKCF1 4-330WRKCF2 4-331WRKCOEF 4-332WRKDBG 4-334WRKDLT 4-323WRKFAIL 4-324WRKFRQ 4-322WRKGP1 4-328WRKGP2 4-329WRKLIM 4-325WRKRIG 4-320WRKRPT 6-381WRKRTO 4-321WRKWLM 4-324WSAL 3-143WSMIN 4-325WSTR 6-385WTC 4-335WTEST 3-145WTRACE 14-643WTRACK 6-393WTRDBG 14-644WTRMAX 3-195WTRPLOT 14-643WTRPMP 4-292WTRTHP 3-183WTV 4-335WWDSP 14-638

XX 8-478XFOFF 3-163XFON 3-163XKC 9-489

KI-668 5000.4.4


YY 8-478YEAR 12-616YES 4-315, 10-529, 10-573, 10-574, 12-616YINJ 3-141YINJA 3-143, 10-535YINJMK 4-253YINJT 4-336YOUNG 10-510, 10-514, 10-554YREINJ 4-254YZERO 4-256

ZZ 3-180, 8-478

5000.4.4 KI-669


KI-670 5000.4.4

Subject
Index
v

000000Subject Index

A

accelerated successive substitution 8-463activate/deactivate grids

in LGR 13-625anion concentration 9-491, 9-493arbitrary gridblock connections

in LGR 13-634area

how defined 4-226injection target 4-239production and injection summaries 6-387production target 4-228

arithmetic operationapplying to grid 8-469

array dataadditional for VIP-DUAL 8-471cross-sections 6-413from VIP-CORE, modifying 8-469modifying for polymer 9-497modifying individual values 8-472modifying values (VIP-DUAL) 8-474printing 9-494printing of 6-374

array reports 6-386artificial lift

at gathering centers 5-341defining methods for 5-348

artificial lift quantity 3-177automatic recompletion units 3-194average pressure

calculation of 6-410Aziz, Govier, Fogarasi correlation 3-205

B

Beggs and Brill correlation 3-205bibliography A-653BLITZ solver 7-447bottomhole injection pressure 3-175bottomhole pressure

additive correction 3-177alternate 3-173damping factor 7-445in hydraulics table 3-169limiting 3-159

bottomhole pressure constraints 3-150bottomhole pressure table

in predictive well management 5-345boundary flux data

file format for 6-413write control 6-392

boundary flux summary 6-388buildup pressure

output control 6-390

C

calcium concentration 9-492cation exchange 9-489CBLITZ iterative matrix solver 13-628CBLITZ solver 7-447chloride concentration 9-491, 9-493comments

inserting lines of comments 1-48compaction regions 8-478compositional model

definition of 1-27content/frequency of output 6-385convergence

5000.4.4 SI-671


tolerances for 7-441convergence failures

how controlled 7-438cross-sections

printing of 6-413

D

damping factorfor bottomhole pressure 7-445

Darcy radial flow equations 3-204data

beginning of 2-75columns to be read 1-50deck layout 1-31injection pressure 3-120injection temperature 3-119line continuation 1-50skip cards 1-50time-dependent 2-57

dead oil modeldefinition of 1-27

debugpredictive well management 5-351wells to be included 5-371

debug outputworkover calculations 4-334

default dimensions 2-58changes for POLYMER option 9-483

defaultschanges in 14-638

densityfor water injectors 3-183of gas, pressure-dependent 3-192

deviated wells 3-80dimensions

changes to 14-638default 2-58

divalent cation concentration 9-492divalent salinity 9-490drainage radius 3-122drawdown

maximum constraint 3-162Dunns and Ross correlation 3-205dynamic vertical flow 3-207, 3-219

E

elevation profilein pipes 10-506

end-of- file marker 2-77endpoint method 3-122enthalpy

of injected steam/water 3-121EXCEL solver 7-447, 7-448external files

how to include 1-49extrapolation of table data 7-445

F

facility utilization summary 6-388faults

conductivesolution options 2-73

transmissibility at connections 8-476transmissibility at connections (VIP-DU-

AL) 8-477field

injection target 4-239production and injection summaries 6-387production target 4-228

field production and injection reports 6-386files

controlling writing of 6-391finite difference formulation

in LGR 13-623flash calculation 8-463

control of 8-464flow modeling

hydraulic tables 10-503in well tubing strings 10-502

flow stationhow defined 4-225injection target 4-239production and injection summaries 6-387production target 4-228

flow vector arrays 2-71fluid tracking 4-335

output 4-336

SI-672 5000.4.4


results file format 6-412tracked fluid 4-336write control 6-393

flux fileformat of 6-413

formulationin LGR 13-623

formulation options 2-64FORTRAN units 1-52free field format

defined 1-47friction loss

in wellbore 3-100front tracking 14-638fuel gas rate 4-246fully coupled calculation 2-73

G

gas conditioning 4-260gas lift

how defined 4-293gas percolation 8-466gas phase hysteresis 8-468gas plant

liquid recovery factor 4-258gas plant data 3-110gas producers

algorithm for 3-178gas rate

minimum for pressure systems 5-354gas reinjection 4-273gas remobilization 8-466gas sales option 4-259gas-oil ratio report 6-388gathering center

how to define 4-225injection target 4-239pressure systems/artificial lift 5-341production and injection summaries 6-387production target 4-228

Gaussian elimination 7-447, 7-448gel

instantaneous 9-493Gibbs energy minimization algorithm 8-461

gradientswellbore 3-164

gridded wellbore 3-204, 3-218grids

activate/deactivate 13-625arbitrary gridblock connections 13-634arithmetic operations on 8-469compaction regions 8-478injection regions 13-634see also LGRwell locations in 13-632

Griffith, Lau, Hon, Pearson correlation 3-205

H

Hagedorn and Brown correlation 3-205Hong’s approximation 9-487horizontal wells 3-100hydrocarbon track file 6-431hydrocarbon volumes

assignment 3-189hysteresis

Land’s constant 8-468

I

IMPES formulation 2-65in LGR 13-623

IMPLICIT formulation 2-64in LGR 13-623

implicit well options 7-453inclined wells 3-100include files

how to specify 1-49injection rate

minimum 4-243injection regions 4-239, 4-274

assigning gridblocks to 13-634injection summary 6-385injection target 3-190, 4-239injection wells

additional injection rate 3-124anions/chlorides 9-491, 9-493assigning to a pattern 3-185

5000.4.4 SI-673


cations/calcium 9-492effective gas target 4-252how defined 3-117how to specify pressure 3-120how to specify quality 3-120how to specify temperature 3-119mobility 3-124polymer concentration in 9-491

inner iterationsdefinition of 7-433

input-outputdiagram of 1-54

instantaneous gel 9-493interactive suspend option 7-456iteration control

for IMPLICIT grids 13-627in LGR 13-626

iteration summary 6-385iterations

for predictive well management 5-340, 10-578

inner 7-433outer 7-433

L

Land’s constant 8-468lift efficiency

vs. water cut 5-370lift gas

composition of 10-535link data

for multi-phase flow 10-522liquid recovery factor 4-258liquified petroleum gas (LPG) plant 4-267

maximum feed rate 4-271maximum rate 4-272

local grid refinement (LGR)overview 13-623

M

makeup gascomposition of 4-253

makeup gas rate 4-249makeup MI rate 4-251map file

array data 9-494format of 2-69inclusion of mole fractions 6-395organization of 6-428specifying arrays to write 6-374water type tracking 6-396

marginal gas-oil ratioin predictive well management 5-369

material balance 2-63material balance error

maximum allowed 7-444matrix solvers

types defined 7-447memory requirements

how calculated 2-58miscible injectant plant 4-264mobility 3-121

for injection wells 3-124mole fractions

printing/mapping 6-395multiphase compositional flow 10-502multi-phase flow

link data 10-522

N

natural gas liquid (NGL) plant 4-261maximum feed rate 4-269maximum rate 4-270

Newton-Raphson method 8-463node connections 10-532node data 10-526node spreadsheet file (SSSUM) 10-560non-Darcy gas flow

near wells 3-192nonlinearity 3-122non-Newtonian fluid viscosity 9-488

O

oil incremental benefit

SI-674 5000.4.4


with gas lift 5-350oil phase hysteresis 8-468oil rate

minimum for flow to pressure system 5-353minimum for pressure system 5-365

Orkiszewski correlation 3-205outer iterations

definition of 7-433how controlled 7-437

output frequencyhow controlled 2-76

output regionsassigning separator batteries 6-398

override modificationin LGR 13-635

P

parallel computing 15-647particle tracking 14-637pattern balancing 3-184pattern element option 3-79perforation relative permeability 3-83perforations

grid location of 13-633in wells 3-83in wells (VIP-DUAL) 3-95

permeability reduction multiplier 9-494phase equilibrium calculations 8-461phase stability test 8-461pipeline network

connecting wells to 10-536general parameters 10-554node connections 10-532node data 10-526options for simulation 10-499pipe data 10-510plotting output 10-564printing data 10-559

plotpipeline network data 10-564production/injection compositional perfor-

mance 6-392production/injection performance 6-392production/injection rate 6-399

plot fileformat/data selection 2-65

compositional 2-66organization of 6-420, 6-424

polymer concentration 9-484, 9-486for injectors 9-491

polymer data 9-483polymer inaccessible pore volume 9-489pore volume

polymer inaccessible 9-489predictive well management

data for steps 2 and 3 5-356debug calculations 5-351how arrays defined 5-340marginal gas-oil ratio 5-369overview 5-339producing areas 5-362producing mechanism 5-363well category 5-364

pressureconstraints on 3-150of injection wells 3-120threshold for limiting grid block to grid

block flow 8-479pressure gradient

modeling in pipes 10-503pressure history

data requirements 1-30pressure system

defining for each well 5-346minimum gas rate 5-354minimum oil rate 5-353, 5-365

pressure systemsat gathering centers 5-341

printing 6-385array data 6-374arrays by cross-section 6-413echo print 1-49mole fractions 6-395pipeline network data 10-559tracer summary report 14-645water type tracking 6-396well and table data 6-399well index 6-412well properties 6-412

producing area

5000.4.4 SI-675


well location in 5-362production history

data requirements 1-30production rate

minimum 4-242tolerances for 5-348

production summary 6-385production targets 4-228

frequency wells created 4-231honoring 4-230in predictive well management 5-342minimum rate 4-237order for reducing phase rate 4-235reducing the phase rate 4-232well rate max. tolerance 4-238

production wellsassign to multiple patterns 3-187how defined 3-115

production/injection compositional perfor-mance

plotting of 6-392production/injection performance

plotting of 6-392pumps

water injectors 4-290

R

radial flow 3-156recurrent data

interactive changes to 7-459region report 6-385reinjected gas

composition of 4-254composition of when zero production 4-

256reports

see printingrestart

how to perform 2-74restart records

defined 1-52save temporary restarts 6-393write control 6-392

results file

control of 2-65RFT report 6-387

wells to include 6-400run termination 2-77run title

how to specify 2-75Russell Goodrich method 3-193

S

sales gas rate 4-248salinity

effective divalent 9-490salinity table 9-484, 9-486scaleback

well rates 4-240secondar recovery projects

design/analysis of 14-637segregated flow

in conductive faults 2-73separator batteries

assigning to output regions 6-398separator battery number

for predictive well management 5-369separator battery report 6-386

selecting batteries 6-397shear rate

effect on viscosity 9-487shrinkage gas rate 4-245shutoffs

limit for automatic shutoff 4-324SIMOUT map files

writing of 6-392simulation statistics 6-388simulator control

overview 7-433single phase injectors 3-182skin factor 3-192

well-rate dependent 3-193solvers

CBLITZ 13-628types defined 7-447

spreadsheet summaryoptions and variables 6-401

spreadsheet summary report 6-388

SI-676 5000.4.4


steam ratefor production wells 3-150

summary recordshow written 1-52

surface facility modeling 3-113surface facility report 6-385surface pipeline network option 10-499surface separators

black-oil modeling (VIP-ENCORE) 3-104compositional modeling (VIP-COMP) 3-

101general data for 3-101k-values 3-107switching 3-112

T

table extrapolation 7-445temperature

for injection wells 3-119temperature gradient profile

in pipes and well tubing 10-505temperature profile

in pipes and well tubing 10-504, 10-509termination of run 2-77time-dependent data 2-57timestep

automatic selection of 7-433controlling size of 2-76how controlled 7-433maximum variable changes 7-440

timestep controlfor IMPLICIT grids 13-626for polymer option 9-496in LGR 13-626

timestep cutshow controlled 7-438maximum variable changes 7-440

timestep sizefollowing well rate changes 7-436how defined 7-434maximum for IMPES 7-439

timestep summarylogical unit for output 6-400

timestep summary report 6-388

titleof run 2-75

tolerancefor convergence 7-441for production rates 5-348

tracer injections 14-641tracer output file 14-643, 14-644tracer summary report 14-645tracer tests

calculation parameters 14-639options for 14-637

trackinginjected water front 14-638of hydrocarbons 6-431

tracking output 6-388transmissibility

at fault connections 8-476at fault connections (VIP-DUAL) 8-477

trapped gasremobilization of 8-466

tubing diameter 3-183tubing length 3-182tubinghead discharge pressure 3-175tubinghead pressure

calculation for gas wells 3-179constraints for single phase injectors 3-182defining for well list 5-342equations, set up 3-161in hydraulics table 3-169iteration control 3-161limiting 3-160table assignment for gas producers 3-179

tubinghead pressure constraints 3-150

U

unitstable of 1-55

utility data 2-57

V

value overridein LGR 13-635

5000.4.4 SI-677


valve coefficient profile 10-507, 10-508vertical wells

name location 3-80VIP-COMP

overview 1-25surface separator modeling 3-101

VIP-COREarray data, modifying 8-469

VIP-DUALfault connection transmissibility 8-477override array values 8-474override modification 8-471overview 1-26well perforations 3-95

VIP-ENCOREdefault separator 3-104overview 1-26

VIP-EXECfiles used 1-52overview 1-25sample input data 1-42

VIP-POLYMERdefault dimension changes 9-483overview 1-27polymer concentration 9-484salinity table 9-484

VIP-THERMoverview 1-27

viscosityfor water injectors 3-183

viscosity tablefor gas wells 3-180

voidage injectionhow defined 4-287

volume balance 2-64

W

water injector pumps 4-290water tracking

mixing parameter 4-338tracked water type 4-338

water tracking report 6-388water type

tracking of 6-396

water-cutvs. lift efficiency 5-370

water-oil hysteresis 3-83well groups

for reporting 6-414well index

printing of 6-412well properties

printing of 6-412well tubing data 10-514wellbore crossflow 3-163wellbore flash control 3-166wellbore gradients 3-164wellbore hydraulics table

assignment of 3-168for injectors 3-175specification of 3-169

wellsangles 3-189artificial lift quantity 3-177average pressure calculation 6-410changing well type class 3-128connections between 10-536constraints on 3-131conventional locations 3-79crossflow in 3-163data for 3-79data requirements 1-30drawdown 3-162dynamic vertical flow 3-207, 3-219economic limit 3-136flash control 3-166flow rates

outer iteration number 3-125fraction of time on 3-146gas rate 3-133gas-oil ratio 3-133gas-oil ratio limits 3-138gradients 3-164grid location of 13-632gridded wellbore 3-204, 3-218hydrocarbon volumes 3-189inclined and horizontal 3-100individual performance 6-392injected gas composition 3-141interval between tests 3-144

SI-678 5000.4.4


lift gas composition 10-535limiting bottomhole pressure 3-159limiting tubinghead pressure 3-160liquid-gas ratio 3-132maximum rate 3-131maximum rate each phase 3-140maximum steam rate 3-150maximum water cut 3-132, 3-135MI injection target 3-190minimum rate 3-139mobility computation 3-124name/location 3-79pattern balancing 3-184perforation tests 3-137perforations 3-83, 3-204perforations (in VIP-DUAL) 3-95predictive management 5-339pressure constraint 3-150production and injection summaries 6-386productivity/injectivity index 3-155radial flow equation data 3-156rate scaleback options 4-240recompletion units 3-194

order for opening 3-197see also injection/production wellstubing diameter 3-183tubing length 3-182tubinghead pressure 5-342type (production/injection) 3-114water cut limits 3-138water-alternating-gas injection 3-198

bottomhole pressure 3-202maximum rates 3-201timestep control 3-203

well index 3-154well lists 1-51well management 4-225wellbore friction loss 3-100

workover rigs 4-320workovers

automatic 4-320benefit function limits 4-325debug output from calculations 4-334elapsed time between 4-323failure rate 4-324frequency of calculations 4-322

relative number 4-321write files 6-391

Z

z-factorfor gas wells 3-180

5000.4.4 SI-679

vip-exec reference manual

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