from the IMEX to - · PDF fileRev 11/1/00:\U_Guides \Sim \CMG \IMEX \Mult_Lat.ppt. ©...

$: from the IMEX to - · PDF fileRev 11/1/00:\U_Guides \Sim \CMG \IMEX \Mult_Lat.ppt. © 2000 Download @ . See license agreement for limited user$
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reated for Laine & Associates, Inc. (Errors may exist. U

se at your own risk.)

You may copy this document (including all “© 2000, Laine & Associates, Inc.” copyright marks) as is, but only for non-profit, personal use. See license agreement for details.

Laine & Associates, Inc.www.EricLaine.com

© 2000

Introduction

to

Black-Oil Reservoir Simulation

featuring

IMEXfrom the

Computer Modelling Group, Ltd

with offices in

Canada, Brasil, Venezuela, Barbados, China, United Kingdom, & United States

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© 2000Preface

Preface

Thank you for visiting www.EricLaine.com.

The primary purpose of this document is to serve as a memory aid for the author.Thus, the author is also the target audience. (In other words, the quality of thecomposition is 100% sufficient for me to understand what I wrote.)

The secondary purpose is to share this tutorial with the public. I appreciate thepossibility that the general public may have some difficulty understanding the mypersonal abbreviations and my intuitive logic.

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© 2000

Laine & Associates, Inc. LICENSE AND WARRANTY NOTICELaine & Associates, Inc. LICENSE AND WARRANTY NOTICE

LAINE & ASSOCIATES, INC. (Laine) LICENSES THIS SOFTWARE TO YOU ONLY UPON THE CONDITION THAT YOU ACCEPTLAINE & ASSOCIATES, INC. (Laine) LICENSES THIS SOFTWARE TO YOU ONLY UPON THE CONDITION THAT YOU ACCEPTALL OF THE TERMS AND CONDITIONS CONTAINED IN THIS LICENSE AGREEMENT. PLEASE READ THESE TERMSALL OF THE TERMS AND CONDITIONS CONTAINED IN THIS LICENSE AGREEMENT. PLEASE READ THESE TERMSCAREFULLY. IF YOU DO NOT AGREE TO THESE TERMS, PLEASE DESTROY THE DOCUMENT(S) YOU HAVE DOWNLOADEDCAREFULLY. IF YOU DO NOT AGREE TO THESE TERMS, PLEASE DESTROY THE DOCUMENT(S) YOU HAVE DOWNLOADEDIMMEDIATELY.IMMEDIATELY.

The software and documents which accompany this license (Software) are the property of Laine or its licensors and is protected byThe software and documents which accompany this license (Software) are the property of Laine or its licensors and is protected bycopyright law. While Laine continues to own the Software, you will have certain rights to use the Software after your acceptance of thiscopyright law. While Laine continues to own the Software, you will have certain rights to use the Software after your acceptance of thislicense.license.

Except as may be modified by a license addendum which accompanies this license, your rights and obligations with respect to the useExcept as may be modified by a license addendum which accompanies this license, your rights and obligations with respect to the useof this Software are as follows:of this Software are as follows:

YOU MAY:YOU MAY:

(i) have limited permission to copy and distribute this Software, but only for non-profit, personal use, provided there is no charge, fee,(i) have limited permission to copy and distribute this Software, but only for non-profit, personal use, provided there is no charge, fee,etc. for said distribution, and further provided that all copyright marks and all references to Laine & Associates, Inc. and toetc. for said distribution, and further provided that all copyright marks and all references to Laine & Associates, Inc. and towww.www.EricLaineEricLaine.com and to Eric Laine are included in the distribution;.com and to Eric Laine are included in the distribution;

(ii) agree that any decision to use some or all of the contents of this Software rests exclusively on your professional and competent(ii) agree that any decision to use some or all of the contents of this Software rests exclusively on your professional and competentjudgment of the suitability of this Software for your intended purpose. Furthermore you understand and acknowledge that this Softwarejudgment of the suitability of this Software for your intended purpose. Furthermore you understand and acknowledge that this Softwarewas originally intended only to be useful to the author, and that you may experience difficulty understanding or using this Software;was originally intended only to be useful to the author, and that you may experience difficulty understanding or using this Software;and,and,

(iii) use the Software on a network.(iii) use the Software on a network.

LIMITED WARRANTY:LIMITED WARRANTY:

Laine does not warrant that the Software will meet your requirements or that operation of the Software will be uninterrupted or that theLaine does not warrant that the Software will meet your requirements or that operation of the Software will be uninterrupted or that theSoftware will be error free. THIS SOFTWARE IS PROVIDED AS IS, WITHOUT WARRANTY OF ANY KIND, EITHER EXPRESS ORSoftware will be error free. THIS SOFTWARE IS PROVIDED AS IS, WITHOUT WARRANTY OF ANY KIND, EITHER EXPRESS ORIMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF PERFORMANCE, MERCHANTABILITY, FITNESSIMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF PERFORMANCE, MERCHANTABILITY, FITNESSFOR A PARTICULAR PURPOSE, ACCURACY, OMISSIONS, COMPLETENESS, CURRENTNESS, AND NON-INFRINGEMENT.FOR A PARTICULAR PURPOSE, ACCURACY, OMISSIONS, COMPLETENESS, CURRENTNESS, AND NON-INFRINGEMENT.THE AUTHOR EXPRESSLY DISCLAIMS ANY REPRESENTATION OR WARRANTY, WHETHER WRITTEN OR ORAL, THAT THISTHE AUTHOR EXPRESSLY DISCLAIMS ANY REPRESENTATION OR WARRANTY, WHETHER WRITTEN OR ORAL, THAT THISSOFTWARE WILL BE ERROR FREE OR UNAMBIGUOUS. YOU ACKNOWLEDGE THAT USE OF THIS SOFTWARE IS AT YOURSOFTWARE WILL BE ERROR FREE OR UNAMBIGUOUS. YOU ACKNOWLEDGE THAT USE OF THIS SOFTWARE IS AT YOURSOLE RISK, AND YOU AGREE THAT ANY INFORMATION, SERVICE OR PRODUCT, WHETHER BASED IN PART OR IN WHOLESOLE RISK, AND YOU AGREE THAT ANY INFORMATION, SERVICE OR PRODUCT, WHETHER BASED IN PART OR IN WHOLEON THIS SOFTWARE, IS WITHOUT WARRANTY, EITHER EXPRESSED OR IMPLIED.ON THIS SOFTWARE, IS WITHOUT WARRANTY, EITHER EXPRESSED OR IMPLIED.

Agreement (1 of 2)

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© 2000Agreement (2 of 2)

Laine & Associates, Inc. LICENSE AND WARRANTY NOTICE, continuedLaine & Associates, Inc. LICENSE AND WARRANTY NOTICE, continued

DISCLAIMER OF DAMAGES:DISCLAIMER OF DAMAGES:

IN NO EVENT WILL LAINE BE LIABLE TO YOU FOR ANY SPECIAL, CONSEQUENTIAL, INDIRECT OR SIMILAR DAMAGES,IN NO EVENT WILL LAINE BE LIABLE TO YOU FOR ANY SPECIAL, CONSEQUENTIAL, INDIRECT OR SIMILAR DAMAGES,INCLUDING ANY LOST PROFITS OR LOST DATA ARISING OUT OF THE USE OR INABILITY TO USE THE SOFTWARE, EVEN IFINCLUDING ANY LOST PROFITS OR LOST DATA ARISING OUT OF THE USE OR INABILITY TO USE THE SOFTWARE, EVEN IFLAINE HAS BEEN ADVISED OF THE POSSIBILITY OF SUCH DAMAGES. SOME STATES DO NOT ALLOW THE LIMITATION ORLAINE HAS BEEN ADVISED OF THE POSSIBILITY OF SUCH DAMAGES. SOME STATES DO NOT ALLOW THE LIMITATION OREXCLUSION OF LIABILITY FOR INCIDENTAL OR CONSEQUENTIAL DAMAGES SO THE ABOVE LIMITATION OR EXCLUSIONEXCLUSION OF LIABILITY FOR INCIDENTAL OR CONSEQUENTIAL DAMAGES SO THE ABOVE LIMITATION OR EXCLUSIONMAY NOT APPLY TO YOU. IN NO CASE SHALL LAINE'S LIABILITY EXCEED THE PURCHASE PRICE FOR THE SOFTWARE.MAY NOT APPLY TO YOU. IN NO CASE SHALL LAINE'S LIABILITY EXCEED THE PURCHASE PRICE FOR THE SOFTWARE.THE DISCLAIMERS AND LIMITATIONS SET FORTH ABOVE WILL APPLY REGARDLESS OF WHETHER YOU ACCEPT THETHE DISCLAIMERS AND LIMITATIONS SET FORTH ABOVE WILL APPLY REGARDLESS OF WHETHER YOU ACCEPT THESOFTWARE.SOFTWARE.

GENERAL:GENERAL:

The author has made a good faith effort to advise all vendors of the software used to develop this Software of his intention to share thisThe author has made a good faith effort to advise all vendors of the software used to develop this Software of his intention to share thisSoftware with others. Those vendors have neither endorsed nor declined to endorse the contents of this Software.Software with others. Those vendors have neither endorsed nor declined to endorse the contents of this Software.

Nothing in this Software will give you any right, title or interest in or to any ofNothing in this Software will give you any right, title or interest in or to any of Laine’s Laine’s trademarks, trade names, service marks, insignia, trademarks, trade names, service marks, insignia,labels or designs, or any of the same, except a mere privilege and license during its term, to display and use the same according to thelabels or designs, or any of the same, except a mere privilege and license during its term, to display and use the same according to theforegoing limitations.foregoing limitations.

Any and all opinions found in this Software are of the author. The author reserves the right to modify any and all opinions as, if, andAny and all opinions found in this Software are of the author. The author reserves the right to modify any and all opinions as, if, andwhen new information is made available. Factual input, whether supportive and dissenting, is welcome. Your input will receive duewhen new information is made available. Factual input, whether supportive and dissenting, is welcome. Your input will receive dueconsideration and will surely affect the author's future efforts. The author expresses advance appreciation for the time and effort youconsideration and will surely affect the author's future efforts. The author expresses advance appreciation for the time and effort youdevote to your communications.devote to your communications.

This is an agreement between you and the author regarding your use of this Software. You agree by your use or possession of any orThis is an agreement between you and the author regarding your use of this Software. You agree by your use or possession of any orall of this Software to the conditions and limitations of this agreement.all of this Software to the conditions and limitations of this agreement.

This agreement is an integral part of this Software. Failure to include this entire agreement in any and all distributions of this SoftwareThis agreement is an integral part of this Software. Failure to include this entire agreement in any and all distributions of this Softwareshall be a breach of this license agreement, and shall not sever, void, or nullify the meaning or the intention of this agreement.shall be a breach of this license agreement, and shall not sever, void, or nullify the meaning or the intention of this agreement.

This Agreement will be governed by the laws of the State of Texas. This Agreement may only by modified by a license addendumThis Agreement will be governed by the laws of the State of Texas. This Agreement may only by modified by a license addendumwhich accompanies this license or by a written document which has been signed by both you and Laine.which accompanies this license or by a written document which has been signed by both you and Laine.

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© 2000

INTRODUCTION

This class is for people who want to be better reservoir simulators. You areabout to learn (or review):1. Basic petroleum-engineering concepts.2. Basic reservoir-simulation concepts.3. Detailed instructions for using IMEX (CMG’s black-oil simulator)

to model realistic data.

This class is for Managers, Engineers, Technicians, and Studentsrepresenting oil and gas Exploration, Operations, Consulting, or Educationalinstitutions. Engineering, Geophysics, or Geology experience is helpful.

The minimum prerequisites are:1. You know that profit predictions come from flow-rate predictions.2. You know that simulation predicts oil rates, natural-gas rates,

water rates, reservoir pressures, and well pressures.3. You know how to use a personal-computer mouse.4. You know how use the page-down key to see the next slide.

This manual includes material copyrighted by the Computer Modelling Group, Ltd.By accepting this manual, the user certifies that (s)he has legal access to a currentIMEX license from the CMG.

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© 2000

THE PLOTCongratulations, this is your first day on your new job. You are personally

responsible for the next phase of an ongoing black-oil reservoir-simulation study.Fortunately, you are bright, aggressive, hard working, and you have good access tothe technical-support gurus for your software and for your project.

So much for the good news.The previous study had a major problem with small timesteps and long run times.

This was caused by pinchouts along the length of the reservoir. The largest cellshad pore volumes over 1,000,000 ft3. The smallest cells had pore volumes under20,000 ft3.

You have raw data in the form of contour maps, PVT tables, relative permeabilitytables, capillary pressure tables, in-place volumes, etc. You also have well-completion data and production history.

The previous work included a history match, so you do not need pressure-historydata for this phase of the study.

Today’s assignment is to create an IMEX data file, correct the small-timestepproblem, and complete a baseline run that realistically represents the reservoir,matches history, and runs quickly.

IMEX is the Computer Modelling Group, Ltd’s IMEX (black-oil) simulator.

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© 2000

IN-PLACE VOLUMES

Pore VolumeTotal 306,717 M STBHydrocarbon 230,038 M STB

Fluids in PlaceStock Tank Oil 144,876 M STBTotal Gas 142,963 MM SCFFree Gas 0 MM SCFWater 76,645 M STBReservoir Oil 230,038 M RBReservoir Gas 0 M RBReservoir Water 76,679 M RB

Average PressureTotal Pore Volume 2513.4 psiaHC. Pore Volume 2513.4 psia

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© 2000

OVERVIEW

Reservoir simulation is similar to a material balance. In fact, simulation includes amaterial balance for each grid (or cell) during every timestep.

Simulation has some advantages over a material balance. Not surprisingly,simulation requires more input than a material balance.

Material balance predicts:Global pressure versus total production and injection.Global pressure versus time (given adequate history.)

Simulation also predicts:Localized 3-phase flow (i.e., by grid block.)Localized production and injection.Localized pressure changes (given minimal history.)Localized saturation changes (given minimal history.)

Not surprisingly, simulation requires more input than a material balance.Material balance input data includes:

Volumetric and PVT data.Global production, injection, and pressure history.

Simulation input also includes:Permeability, relative-permeability, & capillary-pressure data.Localized production, injection, and pressure history.

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© 2000

SIMULATION INPUT-DATA SUMMARYVOLUMETRIC PROPERTIES

Dimensions: area, gross thickness, & net thickness.Pore space: porosity.Saturations: oil, water and gas.Formation volume factors: oil, water and gas.

Total pore volume, rb = 7758.3 (A, ac2) (TNET, ft) (φ, decimal)Oil pore volume, rb = (PV, rb) (SO, decimal)Standard oil volume, stb = Oil PV, rb / (formation-volume factor, rb /stb)

PVT PROPERTIESBubble point: oilFormation volume factors: oil, water and gas.Viscosities: oil, water and gas.Solution gas-oil ratio: gas dissolved in oil

ROCK PROPERTIESPermeability: absolute permeability.

ROCK and FLUID PROPERTIESRelative permeability: oil-water, liquid-gas (or water-gas)Capillary pressure: oil-water, oil-gas (or water-gas)Contact depths: water-oil, gas-oil

PRODUCTION and INJECTION HISTORYFluids: oil, water, & gas rates plus cumulative volumes.Pressure: field and wells.

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10 of 578Created for Laine & Associates, Inc. (Errors may exist. Use at your own risk.)

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SIMULATION OVERVIEW(table of contents)

0. GETTING STARTEDA. GridBuilderB. ModelBuilderC. IMEXD. Results (3D, Graph, and Report)

1. RESERVOIR DESCRIPTION (GRID)A. General data (fluid model, units, and start date)B. Volumetric properties

i. Maps and values of thickness and areaii. Grid

C. Rock propertiesi. Porosityii. Permeability

D. Visualization (2D and 3D grids)E. Null blocks (pore-volume and porosity cutoffs)F. Multi-lateral well (perforation locations)

2. FLUID (PVT) MODELA. Oil and gas tables

i. Solution ratio (RS)ii. Formation-volume factorsiii. Viscosity

B. Water valuesC. Pressure-dependence (oil viscosity, compressibility)

3. ROCK and FLUIDA. Oil-water

i. Relative permeability (KRW and KROW)ii. Capillary pressures (PCOW)

B. Liquid-gasi. Relative permeability (KRG and KROG)ii. Capillary pressures (PCOG)

4. NUMERICAL METHODS

5. INITIAL CONTITIONSA. Contact depths (water-oil and gas-oil)B. Reference pressure at gas-oil contactC. Bubble-point pressure

6. WELLS and RECURRENT DATAA. Select wells and datesB. Initial well (operational) statusC. Production history and unitsD. Well-type definitions and patternsE. Multi-lateral (horizontal) well perforationsF. Constraints

7. VALIDATIONA. Run validationB. Warnings and errors

8. PROOF READINGA. Read the input fileB. Understand the input fileC. Correct in-place volumes (peculiar to this example)

9. HISTORY MATCHING (versus time)A. Global (total-withdrawal) rates (by well)B. Global (average field) pressureC. Local (oil, gas, and water) rates (by well)D. Local (average well) pressures

10. PREDICTIONSA. Stimulation (acid & fracture to increase well index)B. Infill drillingC. Pressure Maintenance (water or gas injection)

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0. GETTING STARTEDA. GridBuilderB. ModelBuilderC. IMEXD. Results (3D, Graph, and Report)

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© 2000

Temp storage for outline.

In process of moving to interior of tutorial.

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2. FLUID (PVT) MODELA. Oil and gas tables

i. Solution ratio (RS)ii. Formation-volume factorsiii. Viscosity

B. Water valuesC. Pressure-dependence (oil viscosity, compressibility)



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3. ROCK and FLUIDA. Oil-water





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4. NUMERICAL METHODS



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5. INITIAL CONTITIONSA. Contact depths (water-oil and gas-oil)B. Reference pressure at gas-oil contactC. Bubble-point pressure



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6. WELLS and RECURRENT DATAA. Select wells and datesB. Initial well (operational) statusC. Production history and unitsD. Well-type definitions and patternsE. Multi-lateral (horizontal) well perforationsF. Constraints



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7. VALIDATIONA. Run validationB. Warnings and errors



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8. PROOF READINGA. Read the input fileB. Understand the input fileC. Correct in-place volumes (peculiar to this example)



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9. HISTORY MATCHING (versus time)A. Global (total-withdrawal) rates (by well)B. Global (average field) pressureC. Local (oil, gas, and water) rates (by well)D. Local (average well) pressures



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10. PREDICTIONSA. Stimulation (acid & fracture to increase well index)B. Infill drillingC. Pressure Maintenance (water or gas injection)



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COMING UP0. GETTING STARTED

A. GridBuilderB. ModelBuilderC. IMEXD. Results (3D, Graph, and Report).

Introduce idea of four primary sections.

Point out that some primary sections are coveredby more than one of the major sections (1 to 10).

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A. GridBuilder - Reservoir Description1. Reservoir description

B. ModelBuilderC. IMEXD. Results (3D, Graph, and Report).

Introduce GridBuilder section.

Identify which section numberscontribute to GridBuilder.

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A. GridBuilderB. ModelBuilder

2. Fluid (PVT) model3. Rock and fluid (KR and PC)model4. Numerical methods5. Initial conditions6. Wells and recurrent data7. Validation8. Proof reading

C. IMEXD . Results (3D, Graph, and Report).

Introduce ModelBuilder section.

Identify which section numberscontribute to ModelBuilder.

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A. GridBuilderB. ModelBuilderC. IMEX

9. History matching10. Predictions

D. Results (3D, Graph, and Report).

Introduce IMEX section.

Identify which section numberscontribute to IMEX.

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A. GridBuilderB. ModelBuilderC. IMEXD. Results (3D, Graph, and Report).

11. 3D12. Graph13. Report

Introduce Results section.

Identify which section numberscontribute to Results.

COMING UP

major section #1: GridBuilder

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0. GETTING STARTEDA. GridBuilder

1. Reservoir descriptionB. ModelBuilder = ALL OTHER INPUT DATAC. IMEX = SIMULATION RUND. Results

0.A. Getting Started

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2. Double Left-click theCMG Launcher icon,

3. Left click the Start button. A. Left click Programs.

B. Left click CMG.C. Left click Launcher.

Start the Launcher

OR


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1. Left double-click the GridBuilder icon.


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REVIEW1. There are four primary sections

A. Reservoir descriptionB. The other inputsC. SimulationD. Results

2. GridBuilder is now running.

COMING UP1. Input general data

A. Simulator selectionB. Working unitsC. Porosity modelD. Start date


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© 20001.A. General data


1. RESERVOIR DESCRIPTION (GRID)A. General data (fluid model, units, and start date)B. Volumetric properties (maps and values)C. Rock properties (KX, KY, KZ)D. Calculate grid (cell) valuesE. Visualization (2D and 3D grids)F. Null blocks (pore-volume and porosity cutoffs)G. Multi-lateral well (perforation locations)H. Save and exit

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1. Left Click the IMEX simulator.

2. Left Click Field Working Units.

3. Set the date to August 1, 1991.

1.A. General data

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2. Left click the OK button.

1. Verify the selections.

1.A. General data

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REVIEW1. General data was input.

COMING UP1. Input volumetric properties.

A. AreaB. Grid definitionC. Structural topD. Gross thicknessE. Net-to-gross-thickness ratioF. Porosity

1.A. General data

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© 20001.B. Volumetric properties


1. RESERVOIR DESCRIPTION (GRID)A. General data (fluid model, units, and start date)B. Volumetric properties (maps, values and grid)

i. Area (from gross thickness map)ii. Gridiii. Structural topiv. Gross thicknessv. Net-to-gross ratiovi. Porosity

C. Rock properties (KX, KY, KZ)D. Calculate grid (cell) valuesE. Visualization (2D and 3D grids)F. Null blocks (pore-volume and porosity cutoffs)G. Multi-lateral well (perforation locations)

H. Save and exit

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© 2000

1. Left click File.

2. Left click Open Map File...

1.B.i. Volumetric - area (TGROSS)

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© 2000

1. Verify the units.

4. Left click the gross net pay map.

5. Left click the Open button.

2. Left click Browse...

3. ...\CMGTutor\IMEX\Mult_Lat\input


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© 2000

1. Verify the WINDIG File selection.



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© 2000

Mapscale is inthe way.


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© 2000

1. Left click View.

2. Left click Properties.

EVEN BETTER3. Right click on the

map scale.


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© 2000

1. Left click the MapScale tab.

2. Change 55 to 5.



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1. Observe.


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© 2000

1. Left click Grid.

3. Left click Non-orthogonal Grid.

2. Left click Corner Point.


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© 2000

1. Read the text.

2. Left click the Next>> button.


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© 2000

2. Left click the first boundarypoint. (This is the first offour line segments.)

1. Read the text.

BOUNDARY points1 -3500.0 55000.02 10000.0 63000.03 62000.0 0.04 52000.0 -6000.05 -3400.0 54000.0


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© 2000

2. Left click the end of theTop-most boundary line.

1. Highlighted dot.

BOUNDARY points1 -3500.0 55000.02 10000.0 63000.03 62000.0 0.04 52000.0 -6000.05 -3400.0 54000.0


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© 2000

2. Left click the Next Line button.

1. Highlighted line.


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© 20002. Read the text.

3. Left click the end ofthe Right-mostboundary line.

1. Observe.

BOUNDARY points1 -3500.0 55000.02 10000.0 63000.03 62000.0 0.04 52000.0 -6000.05 -3400.0 54000.0


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© 2000



2. Delay boundary-lineadjustments until later.


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© 2000

2. Left click the end of theBottom-most boundaryline.

1. Read the text.

BOUNDARY points1 -3500.0 55000.02 10000.0 63000.03 62000.0 0.04 52000.0 -6000.05 -3400.0 54000.0


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© 2000


1. Highlightedline.


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© 2000

2. Left click the end ofthe Left-mostboundary line.

1. Read the text.

BOUNDARY points1 -3500.0 55000.02 10000.0 63000.03 62000.0 0.04 52000.0 -6000.05 -3400.0 54000.0


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© 2000




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© 2000


2. There are no map features to add.

1. There are four highlightedboundary lines.


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© 2000

2. Note: the right- andleft-most boundarylines turned black.

1. Read the text.

3. Create 40 or 20(not10)divisions parallel to the right-and left-most boundaries.

1.B.ii. Volumetric - grid

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© 2000

1. Left click the NextSection button.

1.Bii. Volumetric - grid

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© 2000

1. Note: the top- and bottom-most boundary lines turnedblack.

2. Create 160 or 80 (not30)divisions parallel to the right-and left-most boundaries.


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© 2000



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© 2000

2. The right-most control lineshould include all net pay.

However, we know fromprevious study that this edgepinches out.

1. Read the text.3. Left-mouse-down and drag the corner

points until all the net pay is insidethe boundaries.


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© 2000

3. Create four layers.WARNING: There is an

indication that there isonly one flow unit. If true,then fewer layers will workwell. Perhaps thereshould only be one layer.

1. This is better.

2. Read the text.


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© 2000



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© 2000

1. Review the layers.

2. Read the text.

5. Left click theFinish button.

4. (Optional) Use the Grid, Refine Grid, SelectBox, etc. menu as needed (e.g., defineregions, local grid refinement, etc.)

3. ???Feel free to savethe data file at thispoint. You may thenexperiment with gridrefinement. Openthe saved data file tocontinue without gridrefinements.


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© 2000

1. This is immediately afterclicking the Finish button.


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© 2000

Property-Box Notation:_ = neither specified nor interpolatedB = both specified and interpolatedS = specified onlyV = value only (not specified)

Property-Box1.B.iii. Volumetric - structural top

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© 20001.B.iii. Volumetric - structural top

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© 2000

GROSS THICKNESS

1.B.iii. Volumetric - structural top

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© 2000

GROSS THICKNESS


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© 2000

GROSS THICKNESS


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© 2000

GROSS THICKNESS


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????Only 1layer?

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© 2000

GROSS THICKNESS


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© 2000

GRID TOP

1.B.iv. Volumetric - gross thickness

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© 2000

GRID TOP


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© 2000

1. How about setting GROSS PAY? NETthickness. Then let net-to-gross = con = 1.Maybe can do min PV cutoff this way. YES

GRID TOP


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© 2000

GRID TOP


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© 2000

GRID TOP


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© 2000

Determined from firstline of *.dig file


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© 2000

GRID TOP


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© 2000

GRID TOP


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© 2000

GRID TOP


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© 2000

3. Thickness properties are subdivided by layers

GRID TOP1.B.iv. Volumetric - gross thickness

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© 2000

GRID TOP


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© 2000

GRID TOP


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© 2000

1. Add net-to-gross ratio= YES

Mention possibility of importing net-thickness maps

1.B.v. Volumetric - net-to-gross ratio

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© 20001.B.v. Volumetric - net-to-gross ratio

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© 2000

Highlight POROSITY (notpressure.)

1.B.vi. Volumetric - porosity

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© 20001.B.vi. Volumetric - porosity

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© 2000

REVIEW1. Some properties were imported as contour maps

AreaStructural topGross thicknessPorosity

2. One properties were entered as constants.Net-to-gross (thickness) ratio

3. Any property may be input as a contour map or as a constant.4. Layered properties may be input as two or more maps.

COMING UP1. Input rock properties.

1.B. Volumetric properties

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© 2000


1. RESERVOIR DESCRIPTION (GRID)A. General data (fluid model, units, and start date)B. Volumetric properties (maps, values and grid)C. Rock properties (KX, KY, KZ)

i. KXii. KYiii. KZ

D. Calculate grid (cell) valuesE. Visualization (2D and 3D grids)F. Null blocks (pore-volume and porosity cutoffs)G. Multi-lateral well (perforation locations)

H. Save and exit

1.C. Rock properties

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© 20001.C.i. Rock properties - KX

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© 2000

1. 180 md.

1.C.i. Rock properties - KX

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© 2000

1. 180 md.


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© 2000

1. 180 md.


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© 20001.C.ii. Rock properties - KY

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© 2000

1. 180 md.

1.C.ii. Rock properties - KY

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© 2000

1. 180 md.


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© 2000

1. 180 md.


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© 20001.C.iii. Rock properties - KZ

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© 2000

1. 20 md.

1.C.iii. Rock properties - KZ

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© 2000

1. 20 md.


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© 2000

1. 20 md.


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© 2000

REVIEW1. Some properties were imported as contour maps

AreaStructural topGross thicknessPorosity

2. Some properties were entered as constants.Net-to-gross (thickness) ratioPermeabilities (KX, KY, KZ)

3. Any property may be input as a contour map or as a constant.4. Layered properties may be input as two or more maps.

COMING UP1. Calculate Properties (I.e., populate the grid with values.)

1.C. Rock properties

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© 2000


1. RESERVOIR DESCRIPTION (GRID)A. General data (fluid model, units, and start date)B. Volumetric properties (maps, values and grid)C. Rock properties (KX, KY, KZ)D. Calculate grid values (populate cells)E. Visualization (2D and 3D grids)F. Null blocks (pore-volume and porosity cutoffs)G. Multi-lateral well (perforation locations)H. Save and exit

1.D Calculate grid values

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© 20001.D. Calculate grid values

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1. Left double-click theGridBuilder icon.

1.D. Calculate grid values

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Inv wt avg = 1/ (1/a^2 + 1/b^2 + 1/c^2 + .…)^0.5


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REVIEW1. Grid values were calculated from map and constant input data for:

Grid thicknessGrid topPermeability (KX, KY, KZ)Porosity

COMING UP1. Review 2D and 3D grid maps.


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1. RESERVOIR DESCRIPTION (GRID)A. General data (fluid model, units, and start date)B. Volumetric properties (maps, values and grid)C. Rock properties (KX, KY, KZ)D. Calculate grid values (populate cells)E. Visualization (2D and 3D grids)

i. Grid topii. Grid thicknessiii. Permeability (KX, KY, KZ)iv. Porosity

F. Null blocks (pore-volume and porosity cutoffs)G. Multi-lateral well (perforation locations)H. Save and exit

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1. Left double-click the GridBuildericon.

1.E.i. Visualization - grid top

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© 20001. Left double-click the GridBuildericon.

1.E.i. Visualization - grid top

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© 20001.E.ii. Visualization - grid thickness

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© 20001.E.iii. Visualization - Permeability

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© 20001.E.iv. Visualization - Porosity

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© 20001.E. Visualization

REVIEW1. Grid maps (layers and slices) display

volumetric and rock properties.Grid topGrid thicknessPermeability (KX, KY, KZ)Porosity

COMING UP1. Null blocks

A. Porosity cutoffB. Net-pay-thickness cutoffC. Pore-volume cutoff

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1. RESERVOIR DESCRIPTION (GRID)A. General data (fluid model, units, and start date)B. Volumetric properties (maps, values and grid)C. Rock properties (KX, KY, KZ)D. Calculate grid values (populate cells)E. Visualization (2D and 3D grids)F. Null blocks (pore-volume and porosity cutoffs)

i. Pinchout adjustmentii. Porosity cutoffiii. Net-pay-thickness cutoffIv. Pore-volume cutoff

G. Multi-lateral well (perforation locations)H. Save and exit

1.F. Null blocks

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Pinchout versus Run TimeThe run time for the previous simulation study was too long.The long run time was caused by the small pore-volumecells. The small PV cells are caused by the pinchout at theedge of the -thickness maps.

One way to deal with this is to eliminate the pinchout whilemaintaining the same total pore volume.

See the next slides for details.

1.F.i. Null blocks - pinchout adjustment

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© 20001.F.i. Null blocks - pinchout adjustment

Pinchout Cross-section View

20

25

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5

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Plan View

5

Small PV cells at pinchoutrequire small timesteps (tolimit maximum pressureand saturation change pertimestep.)

Thickness

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RULE-of-THUMB (for small PV cells):Conserve total pore volume

1. Move the small volumes toadjacent cells.

2. Classify the small-volumecells as null (inactive) cells.

3. Total volume is unchanged.

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Pinchout Cross-section View

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Revised Cross-section View

Thickness

Move the small volumes toadjacent cells. (The totalvolume is unchanged.)

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Bracket existing contours with control contours. (I.e., move the smallvolumes to adjacent cells, and maintain the same total volume.)

0 10 20

Revised Plan View

50 10

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REVIEWThe previous example moved the small pore volumes by adding a pair of control

contours. Control contours allow the engineer to force a new reality onto theunderlying maps. This example added control contours with values of 0.0 and 10.0very close to the 5.0 contour.

The thickness maps you are using for this tutorial are modified versions of theoriginal maps. The original maps were modified by adding pairs of control-contourlines. The control contours were added mid-way between the zero contour and theadjacent contour. The control contour closer to the zero line was assigned a valueof nearly zero. The other control contour was assigned a value slightly below theadjacent contour.

As it turns out, the mid-way location of the control contours actually increased thetotal pore volume. This is fine for now. Later, we will find out that there is still ashort-timestep (i.e., long-run-time) problem. We will eventually solve this by addingnull cells (with the pore-volume cutoff.) Then we will correct the total pore volumewith a linear adjustment.

COMING UPThere are easy ways to fine tune the total volumeAND learn more about the reservoir:

The porosity cutoff,The net-pay thickness cutoff, andThe pore-volume cutoff.

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© 20001.F.ii. Null blocks - porosity cutoff

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RULE of THUMBUse the log-analysis cutoffs. Nominal values might be:

four percent for sandstones, andtwo percent for carbonates.

The reservoir engineer probably has some values for you.

1.F.ii. Null blocks - porosity cutoff

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COMING UPUse the porosity cutoff to locate areas of low

porosity. This may be important when planning thefield-development strategy.

This tutorial takes a short cut by setting adifferent porosity cutoff for each layer. In general,the layers will not be identical.


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Show step-by-step setting of different porosity cutoffvalues for each layer. Layer 1.

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Show step-by-step setting of different porosity cutoffvalues for each layer. Layer 2

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Calculate property button ????

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2. Review the porosity maps.

3. Left click on cells toshow cell porosity.

A few cells have low porosity.These may require short timesteps(for a small portion of the run.)

5. Review all layers.


1. Select the probe mode.

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Layer 2 Show map(s) of (different) cutoff values.

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© 2000

REVIEWThe porosity cutoff considers a single criterion.It is easy to imagine a situation where thickness may be

too thin, even though the porosity is above the cutoff.Using the thickness cutoff is an option.The thickness cutoff requires net thickness maps (or

net-to-gross-thickness-ratio maps.)


COMING UPUsing the net-pay-thickness cutoff.

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© 20001.F.iii. Null blocks - net-pay cutoff

Show final step for setting different net-pay cutoff valuesfor each layer.

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1.F.iii. Null blocks - net-pay cutoff

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© 2000

2. Review the Grid thickness maps.

3. Left click on acell to showcornerthicknesses

There are a few thin cells. Thesemay require short timesteps (toavoid large pressure or saturationchanges in small pore-volumecells.



1.F.iii. Null blocks - net-pay cutoffWhat about net thickness (net-to-gross ratio) ????

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© 2000

COMING UPUsing the pore-volume cutoff to fine tune the total pore volume,

and to locate the large-size pore-volume areas.

REVIEWThe thickness cutoff (like porosity) only considers a one criterion.It is easy to imagine a situation where porosity may be too thin,

even though the thickness is above the cutoff.Using the pore-volume cutoff is more general.The pore-volume cutoff requires net thickness maps (or net-to-

gross-thickness-ratio maps.)

1.F.iii. Null blocks - net-pay cutoff

FOR SELF STUDYThis tutorial skips using the net-pay cutoff to locate areas of low

net pay.Be sure to include this step in a real study, because this may be

important when planning the field-development strategy.

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© 20001.F.iv. Null blocks - pore-volume cutoff1.F.iv. Null blocks - pore-volume cutoff

2. Select NullBlocks.

1. Click drop-down box.

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© 20001.F.iv. Null blocks - pore-volume cutoff

Click Specify Property.

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© 2000

DISCUSSIONThe locations of the areas with large-size pore volumes may be

important when planning the field-development strategy.Specify a large-size PVCUTOFF value.This tutorial has identical layers; so, we can set different cutoffs

for each layer. (In general, layers are different.)The total pore volume is 306,000,000 stock tank barrels. The

grid has 6,400 cells. The average pore volume per cell is about270,000 ft3 /cell.

Try 0, 250,000, 500,000, and 750,000 cubic feet for the large-size pore-volume cutoff.

This helps better understand the reservoir.The actual run will use only a small-size pore-volume cutoff.

1.F.iv. Null blocks - pore-volume cutoff

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Show final step for setting different LARGE-sizepore-volume cutoff values for each layer.

Now have net-to-gross ratio, so can NULLbased on pore volume.

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© 2000

2. Use the modified-block-volume maps.

3. Left click on cells to showpore volumes by cell.

A few cells have small porevolumes. These may requireshort timesteps (for a smallportion of the run.)


1.F.iv. Null blocks - pore-volume cutoff3. Review NULL-block maps by layer 1.


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3. Review modified-block-volume maps bylayer 2.

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3. Review modified-block-volume maps by layer 3.

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3. Review modified-block-volume maps by layer 4.

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DISCUSSIONThe largest pore-volumes appear to be on the order of

500,000 ft3.This provides the upper limit for a ratio of small-to-large-

size pore volumes.This ratio is an indicator of the need for limiting saturation

and pressure changes with small timesteps.

COMING UPRepeat the process and identify the small-size PVCUTOFF.Only the small-size cutoff is used during simulation.

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Select Null Blocks.

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Click Specify Property.

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© 2000

DISCUSSIONThe locations of the areas with small-size pore volumes may

be important when planning the field-development strategy.Specify a small-size PVCUTOFF value.This tutorial has identical layers; so, we can set different cutoffs

for each layer. (In general, layers are different.)The total pore volume is 306,000,000 stock tank barrels. The

grid has 6,400 cells. The average pore volume per cell is about270,000 ft3 /cell.

Try 0, 10,000, 20,000, and 30,000 cubic feet for the small-sizepore-volume cutoff.


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Show final step for setting different small-size pore-volumecutoff values for each layer.

Now have net-to-gross ratio, so can NULLbased on pore volume.

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© 2000

DISCUSSIONThe big change (in area) is between 0 and 10,000

ft3. This suggests 10,000 ft3 as a good starting pointfor the small-size PVCUTOFF.


COMING UPSpecify the pore-volume cutoff.Analyze the small-size to large-size

pore-volume ratio.

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2. Specify low-end pvcutoff range at 10,000 ft3.


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3. Calculate property


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PORE-VOLUME CUTOFFA 10,000 to 500,000 ft3 (50:1) ratio of minimum pore volume to

maximum pore volume is large. This may require short timesteps.At test run will be necessary to verify this.If the 10,000 ft3 minimum pore volume is still too small, then we can

manually edit the input-data file to increase the pore-volume cutoff (e.g.,PVCUTOFF 25000.)

Several test runs may be required.

PORE-VOLUME MODIFICATIONIt is also necessary to maintain the same total pore volume.The test run also calculated the total pore volume.If the new total pore volume is within a few percent of the old total, then

manually adding a volume-modification command will fine tune the totalpore volume (e.g., VOLMOD 6400*1.03.)

Several test runs may be required.

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1. RESERVOIR DESCRIPTION (GRID)A. General data (fluid model, units, and start date)B. Volumetric properties (maps, values and grid)C. Rock properties (KX, KY, KZ)D. Calculate grid values (populate cells)E. Visualization (2D and 3D grids)F. Null blocks (pore-volume and porosity cutoffs)G. Multi-lateral well (perforation locations)

i. Locateii. Specifyiii. Map

1.G. Multi-lateral well

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© 2000

Add the multi-lateral well (15-34), but only layer 3.

1.G.i Locate

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© 2000

OR1. Right click on the map to select

the probe mode.

1. Left click on themode dropdownbox to select theprobe mode.

1.G.i Locate

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© 2000

13,44,3 14,44,3 15,44,3

13,46,3

13,47,3

16,44,3

13,45,3

1.G.i Locate

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Will delete the corner marks later

1.G.ii Specify

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© 2000

Vertical well (four layerscompleted from top tobottom.)

1 26,90,3 connect to ‘surface’1 27,90,3 connect to 11 28,90,3 connect to 21 29,90,3 connect to 31 30,90,3 connect to 41 31,90,3 connect to 51 32,90,3 connect to 61 33,90,3 connect to 71 34,90,3 connect to 81 26,91,3 connect to 11 26,92,3 connect to 101 26,93,3 connect to 111 26,94,3 connect to 121 26,95,3 connect to 131 26,96,3 connect to 141 26,97,3 connect to 151 26,98,3 connect to 161 26,99,3 connect to 171 26,100,3 connect to 18

1 14,44,3 connect to‘surface’1 15,44,3 connect to 11 16,44,3 connect to 21 17,44,3 connect to 31 14,45,3 connect to 11 14,46,3 connect to 51 14,47,3 connect to 6

1 14,44,3 connect to‘surface’1 15,44,3 connect to 11 16,44,3 connect to 21 17,44,3 connect to 31 14,45,3 connect to 11 14,46,3 connect to 51 14,47,3 connect to 6

1.G.ii Specify

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© 2000

I,J,K Slab toolbar

1.G.iii Map

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1. RESERVOIR DESCRIPTION (GRID)A. General data (fluid model, units, and start date)B. Volumetric properties (maps, values and grid)C. Rock properties (KX, KY, KZ)D. Calculate grid values (populate cells)E. Visualization (2D and 3D grids)F. Null blocks (pore-volume and porosity cutoffs)G. Multi-lateral well (perforation locations)H. Save and exit

1.H Save and exit

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© 20001.H Save and exit

REVIEWDone with GridBuilder.

COMING UPStart ModelBuilder.

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2. FLUID (PVT) MODELA. ExecuteB. Oil and gas PVTC. Water PVTD. Pressure-dependence

2.A Execute

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© 2000

1. Left mouse-down onthe icon for theGridBuilder data file.

2. Drag and drop the data iconon the ModelBuilder icon.

2.A Execute

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2.B Oil and gas PVT

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© 2000

1. Left double-click the input-folder icon.

2. Left click the pvt.xls icon.

3. Left click the open button.

2.B Oil and gas PVT

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Note: EG = 1/BG.

2.B Oil and gas PVT

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© 2000

1. Highlight the data (to be imported.)

2.B Oil and gas PVT

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© 2000

1. Review PVT data.

2. Double left-mouse click on individual data points to do manual editing.

2.B Oil and gas PVT

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© 2000

Replace (to show datain table.)

2.B Oil and gas PVT

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© 2000

Replace (to show datain table.)

2.B Oil and gas PVT

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© 2000

1. View plots: A. RS vs P

B. BO vs PC. EG vs PD. µO vs PE. µG vs P

Remove OK button click

2.B Oil and gas PVT

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2.B Oil and gas PVT

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1. Left mouse-down and dragindividual points to shift the PVTdata vertically.

2.B Oil and gas PVT

Rev 11/1/00



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2.B

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1. Left click the Apply button.

2.B Oil and gas PVT

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A note

Green light (success.)2.B Oil and gas PVT

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1. Type 4.E-06 <tab>

3. Type 150 < tab >

2. Type 1.01 < tab >

2.B Oil and gas PVT

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Green light (success.)2.B Oil and gas PVT

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© 20001. Left double-click the GridBuilder

icon.


1. Type 4.2E-06 <tab>

2.C Water PVT

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Green light (success.)

2.C Water PVT

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i. Oil viscosityii. Oil compressibility

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???

2.D Pressure-dependence

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© 20002.D Pressure-dependence Save now (generic)

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3. ROCK and FLUID A. Oil-water



3. Rock and fluid properties

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3.A. Oil-water properties

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© 20001. Left double-click the GridBuildericon.


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.


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© 2000

1. Left click on “Sheet1”

2. Confirm data imported.

3. Left click Next.


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© 2000

2. Left click theheading.

1. Right click theblank header.


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© 2000

2. Hold the shift keydown.

1. Left click the firstvalue.

3. Press the right-arrow key 3 times.


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© 2000

2. Press the down-arrow key 12 times.

1. Continue holding theshift key down.


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© 2000

2. Left click thehorizontal scroll-bar

1. Stop holding the shiftkey down.


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© 2000

1. Left click Next.


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© 2000

2. Left click Next.

1. Use the scroll bars andconfirm that the correctdata imported.


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© 20003.A. Oil-water properties

Rev 11/1/00

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© 2000



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© 20003.B. Liquid-gas properties

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© 2000

.

3.B. Liquid-gas properties

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© 2000

1. Left click Apply.


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© 2000

1. Left click OK.


Rev 11/1/00

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377 of 578C





© 2000



Rev 11/1/00

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© 2000

1. Left click OK.


Rev 11/1/00

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379 of 578C






Rev 11/1/00

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380 of 578C





© 2000

2. Finished with Rock Fluid properties.3. Start on Numerical Methods.

Rev 11/1/00



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is d

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incl

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© 2000

2. Left click OK.

1. Scroll down to NCUTS.

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© 2000

3. Finished with Numerical Methods.4. Start on Initial Conditions.

A. Contact depths.B. Reference pressure & depth.C. Bubble point pressure.

Rev 11/1/00

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2. Left clickinitialconditions.

Success.

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1. Left click the Miscellaneous tab.

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© 2000

1. Left click PVT Region Parameters.

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© 2000

1. Left click PVT Region 1.

2. Type 15000 tab.

3. Type 600 tab.

4. Type 4500 tab.

5. Type 2500 tab. InitialPressure.


Rev 11/1/00

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© 2000

Initial pressure.

PCOG.

PCOW.

6. Left click OK.

1. Verify entry unites.

2. Verify entry values.

Rev 11/1/00

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© 2000

For output and reports.?????


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Succ

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© 2000

1. Review the bubble-point settings.

2. Left click File.

3. Left click Close.

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1. L

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Appl

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© 2000

1. Left mouse-down and drag thevertical scroll slider.

2. Review the grid properties.

Success.

Rev 11/1/00

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© 2000

1. Left mouse-down and drag thevertical scroll slider.

2. Review the gridproperties.

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© 2000

2. Left click OK.

1. Review the gridproperties.

Rev 11/1/00



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1. Confirm the path and filename.

2. Check (or uncheck.) Small filesare suitable for single files.

3. Left click OK.

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© 2000

4. Finished saving .5. Start on Wells and Recurrent Data.

A. Select well dates and wells.B. Set initial well status.C. Import production history.D. Save production history.E. Define wells.

a. Types and Patternsb. Perforations

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1.R

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414 of 578C





© 2000

1. Select Properties.

3. An alternative is toA. click the Wells folder (????)B. click the Wells menuC. click the Properties option.

OR

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418 of 578C





© 2000

1. Click well 15-34.

2. Hold the Ctrl key down.

3. Click well 16-7.

4. Click well 11-5.

6. Click well 6-4.

5. Click well 4-6.

7. Release the Ctrl key.

Wells may be selected in any order.

9. Click the right-arrow button.

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422 of 578C





© 2000

5B. Set initial well status to SHUTIN.

i. No wells are producing on August 1, 1991ii. Only well 6-7 has been drilled by August 1, 1991

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424 of 578C





© 2000

1. Click the Status box.

2. Click the dropdown box.

5. Click OK.

3. Left click SHUTIN. 4. Confirm SHUTIN.

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431 of 578C





© 2000

Note column numbers, data types and units.

Note units for all 5 data columns.1. Date (format = Y M or Y M D)2. Producing hours3. Daily oil rate (stb/d)4. Daily gas rate (Mscf/d)5. Daily water rate (stb/d)

Clean up the data file to show “fixed”column spacing.

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433 of 578C





© 2000

1. Read instructions

2. Click the first data line.

3. Review dataformat options.

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449 of 578C





© 2000

1. Click the dropdown box tomove up one directory level.

1. Enter the filename.(prod.fhf)

2. Click Save.

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450 of 578C





© 2000

1. Confirm the pathand filename.

3. Click Finish.

2. Confirm thestart date.

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452 of 578C





© 2000

1. Ignore productioncontrols for now.

2. Select All Wells.

4. These buttons setthe well types. 3. Observe the

well types.

1 of 3

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453 of 578C





© 2000



4. These buttons setthe well types.

3. Observe theimport types.

2 of 3

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454 of 578C





© 2000



4. These buttons setthe well types.

3. Observe theimport (well)types.

3 of 3

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455 of 578C





© 2000

2. Click Next.

1. Confirm correct Import (well)Types (i.e., what is theprimary fluid for this well.)

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456 of 578C





© 2000

1. Confirm 1.000 for all wells.

For future reference, a cornerwells in a 5-spot are 0.250.

2. Click Next.

Oil (and gas) fraction is for producing wellsWater fraction is for injection wells

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459 of 578C





© 2000

OR

1. Click Wells.

2. Click Perforations.

3. Right click the Wells folder.

4. Click Properties.

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461 of 578C





© 2000

Vertical well.

No skin damage.

Centered well.

Kelly Bushing is at sea level.

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462 of 578C





© 2000

Input dataDO correct the vertical-well perforations:

16-7 layers 2, 3, and 4.11-5 layers 2, 3, and 4.4-8 layers 2, 3, and 4.6-4 layers 2, 3, and 4.

Do NOT use this feature for well 15-34. Thehorizontal-well perforations were set whiledefining the multi-laterals.

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464 of 578C





© 2000

Vertical well completionsdefault to all layers.

2. Click the upper-mostcompletion layer (2.)

3. Click OK.

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466 of 578C





© 2000

2. Click Update perforations.

3. Click Current Well - All Perf Dates

Apply the corrected perforations to the model.

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467 of 578C





© 2000

2. Repeat the perforation corrections for the other vertical wells. (6-4, 11-5, & 4-8)

1. Verify the perforations.

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468 of 578C





© 2000

REVIEWThe perforations are now correct in all five wells.

A. The four vertical wells have been corrected.B. The horizontal well was already correct.

COMING UPSave the perforation corrections.Close the perforation file.

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469 of 578C





© 2000

Wise users will make a note to review thecompleted data file to verify that the perforationsare correct.

delete

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475 of 578C





© 2000

REVIEWThe perforations have been defined and saved.

COMING UPWell constraints

A. Select the wells.B. Delete the default, flowing-bottom-hole pressure constraint.C. Add columns of information to the constraint window.D. Review the constraints for each well.E. Select the wells.F. Set a new flowing-bottom-hole pressure constraint.G. Review the well constraints.H. Close the “Recurrent Data” window.I. Save the Mult_Lat data file.

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476 of 578C





© 2000

1. Right-clickthe Wells.

OR

1. Click Wells.

2. ClickConstraints.

2. ClickConstraints.

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477 of 578C





© 2000

1. Left click Selectall dates.

3. Left click Select Wells.2. Left click Select

one or more wells.

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478 of 578C





© 2000


2. Left click wells 11-5,15-34, 16-7, 4-8, & 6-4.


4. Click right-arrow button.

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481 of 578C





© 2000

1. Double-left-click the vertical lines to automatically set column widths.

2. Left-mouse-down and dragthe vertical scroll bar to verifythe well and date selections.

OR

2. Click above (or below)the slider to scroll.

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483 of 578C





© 2000


A. Select the wells.B. Delete the default, flowing-bottom-hole pressure constraint.C. Add columns of information to the constraint window.D. Review the constraints for each well.E. Select the wells.F. Set a new flowing-bottom-hole pressure constraint. G. Review the well constraints.H. Close the “Recurrent Data” window.I. Save the Mult_Lat data file.

PROGRESS

All wells for all dates have been selected.

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486 of 578C





© 2000

4. Left click the OK button.Delete the constraint.

3. Click “OPERATE MINPressure (Bottom-Hole)”.

1. Read the instructions.

2. Left click the box.

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489 of 578C





© 2000

Show more columns in the constraints window.

2. Click View.

3. Click Columns.

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490 of 578C





© 2000

1. Hold the control key down.

2. Click the properties.

6. Click the right-pointing arrow.

Click Constraints.

Click Well Status.

Click Well Type.

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501 of 578C





© 2000

1. Left click Selectall dates.

3. Left click Select Wells.2. Left click Select

one or more wells.

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505 of 578C





© 2000

1. Drag the vertical lines to change the column widths.

2. Drag the sliderto see more.

OR

2. Click the arrowto see more.

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512 of 578C





© 2000

Set the bottom-hole pressure.

3. Press the Tab key.

2. Type 500.

4. Verify the units.

5. Click OK.

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514 of 578C





© 2000

1. Verify the constraint.

2. Click OK.

3. Left-click the “No To All” button.It’s the same five well-date combinations.

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515 of 578C





© 2000

1. Click Wells.

2. Click the arrow.

3. Click a date.

4. Review the constraints.

Review the well constraints.

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518 of 578C





© 2000

2. Left-click OK.

4. Left-click OK.

6. Left-click OK.

4. Left-click OK.

7. Left-click OK.

Pt 1 and Pt 3 will soon be deleted (because they are not wells.)They are convenient markers used to identify the grid boundaries (for this tutorial.)

Well 16-7 is OK.

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520 of 578C





© 2000

2. Click Wells.

3. Click Delete.

Delete the grid-boundary markers (Pt 1, etc.)

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523 of 578C





© 2000

3. ClickYes.

Re-confirm each deletion.

2. ClickYes.

Verify the non-wells are gone.

5. Click Wells.

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524 of 578C





© 2000

2. Click File.

3. Click CloseRecurrent Data.

Close the “Recurrent Data” window.

Rev 11/1/00



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REVIEW

Well constraints are done.

5. Wells and recurrent data window is closed.

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Save the “Recurrent and Well Data.”

1. Click File.

2. Click SaveDataset As.

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The filename and path should still be correct. (Browse and change if needed.)

4. Click OK.

3. Click Save all...

2. Verify path and name.

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3. click OK.

1. Read the warning.

This is good. It is easier tokeep track of wells by name.

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COMING UP6. Validate the data.

A. It is never too soon to save the data (again.)B. Review the validation message file.C. Understand warnings. Fix errors (and warnings.)D. Close the validation-message file.E. Exit the “ModelBuilder.”F. It is never too soon to save the data (again.).G. Proofread (and understand) every line in the data file.

(Be sure this data file does what you want it to do.)

REVIEW

5. Wells and Recurrent Data aredone.

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WISDOM: It is NEVER TOO SOON to save the data again.

2. Left-click Yes.

3. Left-click the “OK” button.

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A. It is never too soon to save the data (again.)B. Review the validation message file.

i. Understand warnings (and fix as needed.)ii. Fix errors.

C. Close the validation-message file.D. Exit the “ModelBuilder.”E. It is never too soon to save the data (again.).F. Proofread (and understand) every line in the data file.

(Be sure this data file does what you want it to do.)

REVIEW

6A. The data has been saved (again.)

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1. Review the message file for errors or warnings.

OK.

3. confirm that thisis OK.

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Confirm that the warning about setting the minimumflowing bottom-hole pressure to 14.6959 psia is OK.

There are at least two easy ways to confirm this.1. Open Mult_Lat.dat in an ASCII editor (e.g., WordPad.)

A. Search for 14.6959It does not exist in the data file

B. Search for MIN BHPThere are several, all set to 500 psi.

2. See the next slides.

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DATE 1991 08 01. WELL 1 '16-7' PRODUCER '16-7'

===================== WARNING (from subroutine: WMWTIN) Minimum bottom hole pressure not specified for producer 16-7 (Well No. 1). Setting default MIN BHP of 14.6959 psia . ===================================================== GEOMETRY K 0.354167 0.3700 1.0000 0.000 PERF GEO '16-7' ** if jf kf ff 5 54 2 1.000 5 54 3 1.000 5 54 4 1.000 SHUTIN '16-7'

The following extract from Mult_Lat.out clearly shows that on August 1,1991, the minimum PWF is set at 14.6959 psia. Well 16-7 is also shutin.

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No Wells have been operated in the Field. ====================================================== DATE 1991 09 01. PRODUCER '16-7' OPERATE MAX STO 2397.15 OPERATE MIN BHP 500 CONT ON-TIME '16-7' 1.00

The following extract from Mult_Lat.out is the very next timestep. Thisextract clearly shows that on September 1, 1991, the minimum PWF isset at 500 psi. Well 16-7 is producing 2397.15 barrel per day.

Searching Mult_Lat.out confirms that the only time the minimum,flowing bottom-hole pressure is 14.6959 is on August 1, 1991.

In summary, the warning about MIN BHP = 14.69659 is OK.

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C. Close the validation-message file.Exit the “ModelBuilder.”It is never too soon to save the data (again.).

D. Proofread (and understand) every line in the data file.(Be sure this data file does what you want it to do.)

REVIEW

6B. The message review is done.

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1. It is NEVER TOO SOON to save the data again.

2. Left-click Yes.A. Automatically reuses the same directory.B. Automatically reuses the same file name.

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C. Close the validation-message file.Exit the “ModelBuilder.”It is never too soon to save the data (again.).

D. Proofread (and understand) every line in the data file.(Be sure this data file does what you want it to do.)

REVIEW

6C. The automated validation is done.

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RULE OF THUMB:

Always understand every every line in the data file.(Save time by avoiding unnecessary simulations.)

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******************************************************************************************* ModelBuilder has detected a conflict in well sequence numbers.** The well sequence numbers are not increasing consecutively as** required for the simulators. In order to ensure compatibility** with simulators ModelBuilder has to re-number the wells.** All references to wells in this dataset should be in terms of well names.*****************************************************************************************

For example:(see lines 7824-30)

Calling wells by name simplifies things. It is nolonger necessary to also keep track of thesequence numbers.

?????

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COMING UP

7. Fix the volume-in-place values.A. Trial run the data set as is.

(Note the volumes.)B. Correct the in-place volumes.

(Manually edit the data.)i. PVCUTOFF.ii. VOLMOD.iii. Maps from GridBuilder.

8. Run IMEXA. Make the real IMEX run.B. Exit the IMEX run window.

Review the IMEX results.C. Save and exit.

REVIEW

6D. The proofreading is done.

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1. Left-mouse-down and drag the data file to the “IMEX” icon.

2. Release the mouse to start IMEX.

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1. You can watch IMEX’sprogress as it runs.

Do it first with min vol too smallExperience the tiny timesteps.

Then give correct answer asPVCUTOFF = 200,000 ft3???

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1. This field has a pinch out. This means some cells have very small pore volumes.2. The next slides show how to eliminate the small PV cells by editing Mult_MB.dat

Too much saturationchange in small PV cell.

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COMING UP

7. Fix the volume-in-place values.A. Trial run the data set as is.

(Note the volumes.)B. Correct the in-place volumes.

(Manually edit the data.)i. PVCUTOFF.ii. VOLMOD.iii. Maps from GridBuilder.



REVIEW

7A. The trial-run is done.

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But first, get total pore volume, etc. rightNeed to manually insert a STOP card near DATE 1Nov91.This will allow us to search for TOTAL PORE VOLUME.

We want it to be too high.Once know PV too high, remove STOP. Make run.May need to increase PVCUTOFF to avoid 0.001 day

timesteps. This will reduce Total PV.Once get decent minimum timestep (ie good run time) Do

VOLMOD to fine tune total PV.

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PVCUTOFF ft3 n.a. 250,000 250,000VOLMOD n.a. 1.00 1 1.03case Mult_MB.dat MultLatM MultLatN

units orig qtyMinimum Timestep size days 0.0001 1Total Pore Volume. M STB 306,717 293,783 305,484HC. Pore Volume M STB 230,038 220,337 229,113Fluids in Place

Stock Tank Oil M STB 144,876 138,766 144,293Total Gas MM SCF 142,963 136,935 142,389Free Gas MM SCF 0Water M STB 76,645 73,412 76,337Reservoir Oil M rbbl 230,038 220,337 229,113Reservoir Gas M rbbl 0Reservoir Water M rbbl 76,679 73,446 76,371

Average PressureTotal Pore Volume psia 2513.4 2513.4 2513.5HC. Pore Volume psia 2513.4 2513.4 2513.5

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1. The very small blocks tend to be at the edges.2. An exception is near cell i=17, j=27 ,k=1 to 4.

Large pore volume~ 1,960,430 ft3

Small pore volume ~ 48 ft333

Acceptable min PV~ 19,604 ft3 (100:1)

Note: the multi-lateral well is closeto the pinchout(34,90,3)

Help the class by pointing outthat we got this by puttingmult_lat.dat back into gridbuilder.

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Changing the Pore-Volume Cutoff

1. Make a copy of Mult_MB.dat2. Rename the copy Mult_MBa.dat3. Open Mult_MBa.dat in an ASCII editor.4. Search for

RESULTS SECTION ROCKCOMPACTION5. Add two lines after “results section rock compaction.”

“PVCUTOFF 20000”This makes 20,000 ft3 the minimum pore volume.

“VOLMOD 25600*1.00This multiplies the PV in all 25,600 cells by 1.00.

6. Save Mult_MBa.dat7. Go to next slide

After

RESULTS SECTION ROCKCOMPACTIONPVCUTOFF 20000VOLMOD 25600*1.00

RESULTS SECTION MODELMODEL *BLACKOIL

Before

RESULTS SECTION ROCKCOMPACTION

RESULTS SECTION MODELMODEL *BLACKOIL

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Changing the Pore-Volume Cutoff

8. Go to the top of the file9. Search for

1993 0110. Replace a blank line above DATE 1993 01 01. with

STOP11. Save Mult_MBa.dat12. Close Mult_MBa.dat.13. Run IMEX with Mult_MBa.dat14. Open Mult_MBa.out in an ASCII editor.15. Search for

HC. Pore Volume16. Go to next slide

After 1.00

STOP

DATE 1993 01 01.

PRODUCER '16-7'OPERATE MAX STO 1998.584OPERATE MIN BHP 500 CONT

Before 1.00

DATE 1993 01 01.

PRODUCER '16-7'OPERATE MAX STO 1998.584OPERATE MIN BHP 500 CONT

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Record Pore Volumes, etc.

17. Verify Time = 0.0 days (for this particular HC. Pore Volume.)18. Save key volume data.

This will help set the multiplier for VOLMOD 25600*1.__19. Close Mult_MBa.out.20. Use your best judgement to estimate the Minimum Time Step size.

PVCUTOFF ft3 n.a. 20,000 50,000 100,000 100,000 100,000 100,000VOLMOD n.a. 1.00 1.00 1.00 1.00 1.20 1.25 1.23+case Mult_MB.dat_Mba.dat _MBc.da _MBe.dat f.dat f.dat g.dat

units orig qty rev qty rev qty rev qty rev qty rev qtyMinimum Timestep size days 0.0001 0.01 .01 1 1 1 .002Total Pore Volume. M STB 306,717 303,168 285,275 223,238 295,215 312,753 305,628HC. Pore Volume M STB 230,038 227,376 213,957 167,428 221,411 234,565 229,221Fluids in Place

Stock Tank Oil M STB 144,876 143,200 134,748 105,443 139,441 147,725 144,360Total Gas MM SCF 142,963 141,309 132,969 104,051 137,601 145,775 142,454Free Gas MM SCF 40e-13Water M STB 76,645 75,758 71,286 55,783 73,770 78,152 76,372Reservoir Oil M rbbl 230,038 227,376 213,957 167,428 221,411 234,565 229,221Reservoir Gas M rbbl 41e-13Reservoir Water M rbbl 76,679 75,792 71,319 55,809 73,804 78,188 76,407

Average PressureTotal Pore Volume psia 2513.4 2513.3 2512.5 2508.5 2510.3 2510.5 2510.4HC. Pore Volume psia 2513.4 2513.3 2512.7 2508.5 2510.3 2510.5 2510.4

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Record Pore Volumes, etc.

21. Go back to step 122. Repeat the steps for Mult_MBb.dat, Mult_MBc.dat, etc. until:

the nominal time-step size is acceptable,the pore volumes are close enough, andthe fluid in-place-volumes are close enough.

23. Close enough means the customer, boss, etc. is satisfied.

Wisdom

Note:Global use of VOLMOD is a convenient shortcutIt works because the water-oil contact below the reservoir,and because the gas-oil contact is above the reservoir.The rigorous way to deal with the small pore volumesremoved from the pinchout neighborhoods is to selectivelyadd the deleted PVs to the adjacent cells. This keeps thedeleted volumes as close as possible to their original locations.

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COMING UP7. Fix the volume-in-place values.

A. Trial run the data set as is.(Note the volumes.)

B. Correct the in-place volumes.(Manually edit the data.)i. PVCUTOFF.ii. VOLMOD.iii. Maps from GridBuilder.



REVIEW

7B. The in-place volumes are correct.

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COMING UP7. Fix the volume-in-place values.

A. Trial run the data set as is.(Note the volumes.)

B. Correct the in-place volumes.(Manually edit the data.)i. PVCUTOFF.ii. VOLMOD.iii. Maps from GridBuilder.



REVIEW

8A. The real IMEX run is done.

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1. Left mouse-down on Mult_MB.irf.2. Drag Mult_MB.irf to the Results

3D icon.

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COMING UP

9. Predictions (another lesson.)

REVIEW

8B. The IMEX results review is done.

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DISCUSSIONCongratulations. Your first day at you new job was a big success.

You performed several functions.Imported: Map data.

PVT data.Relative-permeability and capillary-pressures.Production history.

Set: Rock properties.Well completions.Well constraints.

Corrected: Well completions.The in-place volumes.

Analyzed: Data, warnings, and results.Archived: Data and results.

Go ahead and congratulate yourself. You can now say that you havecreated and ran a 6,400-cell black-oil model. This tutorial will help youdo it next time too.

You might even thank the boss for picking CMG’s IMEX as thecompany’s preferred black-oil simulator.

from the IMEX to - · PDF fileRev 11/1/00:\U_Guides \Sim \CMG \IMEX \Mult_Lat.ppt. ©...

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