Wellplan Training 2

TM

WELLPLAN Software Release 5000.1 Training Manual

© 20 12 Halliburton

HALLIBURTON

I

Landm rk Softw re & S rvic a

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WELLPLANTM Software

Release 5000.1.10 Training Manual Getting Started . ... .. .... ... .. .. .. ... ... .. ... ............. ... .... ... . .. .1-1 Manual Overview ....... . ... ...... . ................... ................ 1-1 Data .... . . .... .. ............... .. ...... . ............... . ........... I- 1

Technical Support Information ......................................... 1-2

Basics .. . ........................... . ...................................

1-1

Overview . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-1 Exercise l: Creating the Data Hierarchy . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-1 Exercise 2: Specifying Tubular Properties and Working With Catalogs ....... .. 1-1 Exercise 3: Using the Case Menu and Libraries, and Configuring the Workspace . 1-1

Exercise 1: Creating the Data Hierarchy . . ... .. . ..... . . ................ 1-2 Steps and Questions .... ............. ............ . ... ...... .......... 1-2 Answers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-4

Exercise 2: Specifying Tubular Properties and Working With Catalogs . . 1-12 Steps and Questions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-12 Answers . . . . . . .. . . .. . .... . . ... ... . .. . ... . .... . .. . .. . . .. . ... ... . .. 1- 14

Exercise 3: Using the Case Menu and Libraries, and Configuring the Workspace .... ........ ........ . ........... . . ....................... 1-21 Steps and Questions . . .. .... . ..... . . .. . . ... ...... .. .. . .... . ........ . Using the Case Menu . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Using Libraries . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Configuring the Workspace ............. .. ....... .. . .... . ...... . . . Configuring and Using Plots .. . .. . . . .. . ... . ..................... . .. Answers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Using the Case Menu ................ . ........................ . . . Using Libraries . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

WELLPLAN ™ Software Release 5000.1.10 Training Manual


1-21 1-2 1 1-24 1-24 1-26 1-29 l-29 1-36

Contents

Configuring the Workspace ....................................... 1-46 Configuring and Using Plots. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . l-59

Drilling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2- 1 Overview .............. . ... . ................................ .... . . . . 2-1 Data ..... . . . .. .. . ..... .. ... . . ...................... . . . .. .. . .. . .... Workflow .............. ... . .... . . . . .................... . . ......... Workflow Solution ...... ....... . . .. . .... .. ............. ........... . . What Is Covered .. . . ......... ......................... .... . .... . .. .. Input General Well Data . ...... . . ... .. ................ ........ . . ... To rque Drag Analysis ................. . ....... ...... . ... . . ........ Hydraulics Analysis ........... ............ ..... .................. Surge Swab Analysis ..... ............................... . ... . ... . Well Control Analysis ................. ........... ................ Critical Speed Analysis ............................................ Bottomhole Assembly Analysis .......... ........... ................ Stuck Pipe A nalysis .... . . . .. ............................ . ..... ...

2-1 2-1 2-2 2-2 2-2 2-2 2-3 2-3 2-3 2-3 2-4 2-4

Torque Drag Analysis (Using the Torque Drag Analysis Module) ...... . . 2-5 Data lmport for Exercises ............... ... . ... ....................... Input and Review Well Configuration and Analysis Options ................. Analyze Results at TD .. .. ........................................ . .. Analyze Torque and Drag at Other Depths .......................... . . . . .

2-5 2-5 2-7 2-9

Analyze Hydraulics (Using the Hydraulics Module) ............... . ... 2-10 Input a nd Review Well Configuration and Analysis Options ................ Analyze Hole Cleaning . .. . .. . . .............................. .. . ..... Analyze Pressure Loss and Annular Velocity ............................ Determi ne Required Horsepower . .. ............................... . . . . Check ECDs ........ .... ........................................ . . Bit Optimization ............................................... .... Final Design Check ................ ............... ..................

2- l0 2-10 2- 1 l 2-13 2 -1 3 2-14 2- 15

Analyze Surge/Swab Pressures and ECDs (Using the Surge Module) . . . 2-16 lnput and Review Well Configuration and A nalysis Options .............. .. Analyze Transient Responses .... . . ...................... . .... . .. ..... Tripping Out Operation .......................................... Tripping Jn Operation ...... ....... . .... .................... . . . ...

ii

2-16 2 -17 2-17 2- 17

WELLPLAN™ Software Release 5000. 1. 1O Training Manual


Contents

In vestigate Well Control (Using the Well Contro l Analysis Module) . . .. 2 -1 8 Inp ut and Review Well Configuration and Analysis Options ..... ........... Determine Kick Type . . .. ........ .... .......... . ..... ............ ... Estimate Influx Volume .. ............. ............ .. . .......... ... . . Analyze Kick Tolerance . .. .. . ........... ....... ................. . .. . Use Animation to Review Results ............... ............ .... ... .. . Generate a Kill Sheet . . .... . . ..... ............ ...... . .. ... ... . . .. . . .

2- 18 2- 18 2- 19 2- 19 2-20 2-20

Determin e Critical Rotational Speeds (Using C riti cal Speed Module) ... 2-23 Input Analysis Parameters .. . . . . . . . .... . .... .. ......... .... . ... . ... . . Examine the Stresses Acting on the Workstring . .................. . . . .. . . Exam ine String Displacements . . . .. . . ..... ... ........... . . . . .......... Review Bending Moments and Shear Stresses ....... . . ... . ............... Review Results in 3D Plots ................................ . .. ... . ...

2-23 2-24 2 -25 2-25 2-25

Predict BHA Build and Drop (Using Bottom Ho le Assembly Module) .. 2-26 Input Analysis Parameters and Review Resu lts ... .......... .............. 2-26 Determine Where BHA Contacts the Wellbore ................ . . ... . ... . . 2-27 Evalua te Effect of WOB and ROP ........ .... ..... .... ... . ... ......... 2-28

Stuck Point Analysis (Using Stuck Pipe Module) ........ ............ . . 2-29 Inpu t General Analysis Parameters .............................. .. . .... Determine the Stuck Point .. ............ ... ..................... . . ... Setting and Tripping the Jar .......... . . . ................ . . .... .. ..... Yie lding the Pipe ...... .......... .. .. ..... ........ . ...... ...... . ... Backi ng Off. . ..... . ....... .... . . . . ................ ... . . ...........

2-29 2-30 2-30 2-30 2-31

Drilling Solution .. .. . ...... ..........................................

3- 1

Overview ............. .... . .. ........................ ... . . . . . . ...... 3- 1 Torque Drag Analysis (Using the Torque Drag Analys is Module) ........ 3-2 Input and Review Well Configuratio n and Analysis Options ....... .. .. ...... 3-2 Analyze Results at TD ........... .......... . ... ............ ..... .... 3-13 Analyze Torque and Drag at Othe r Depths ................. ....... . ... . . 3-27

A nalyze Hydraulics (Using the Hydraulics Module) ... ... .. ... . . . ... . . 3-32 In put and Review Well Configuration and Analysis Options ........ ..... .. . 3-32 Analyze Ho le Cleaning ...... ... ... ............ ..... . ... . .... . . . . . ... 3-34

WELLPLAN TM Software Release 5000. 1. 1O Training Manual


iii

Contents

Analyze Pressure Loss and Annular Velocity ............... .. . .... . ..... Determine Required Horsepower .. . . . . .. . .. . ........ . ...... .. .... . .. .. Check ECDs . .. ................. .... .. ........ . ...... . .. ... .. . .... Bit Optimization .... . ....... ...... ... ......... . . ...... ....... . .... . Final Design Check ...... . .. . ........ ... .. ............... . . .. . .. ....

3-4 1 3-49 3-53 3-56 3-60

Analyze Surge/Swab Pressures and ECDs (Using the Surge Module) .. . 3-63 Input and Review Well Confi guration and Analysis Options . .. .. ...... . ... . Analyze Transient Responses . ............ .... . ..... . ... . .. . .. . .... . .. T ripping Out Operation . ... .. . . .... . ................. ........ .. .. Tripping In Operation .. . ..... .... .. .. ....................... . ....

3-63 3-64 3-64 3-68

Investigate Well Control (Using the Well Control Analysis Module) . . .. 3-70 Input and Review Well Configuration and Analysis Options .. . .... . ....... . Determine Kick Type . ... . . .. ... ... . .... .. . . ... . . . . .... .. . .... . .. . .. Estimate Influx Volume .... . .. . .. . ............. . .... .. ............. . Analyze Kick Tolerance . ...... ............................ . ... . ... . . Use Animation to Review Results . ....... . ..... . .. . . . .... . .. . . .. . ..... Generate a Ki ll Sheet ... . . . ...... ... . .... . ...... .. .. ......... . .. . . ..

3-70 3-72 3-73 3-74 3-83 3-84

Determine Critical Rotational Speeds (Using Critical Speed Module) . . . 3-93 Input Analysis Parameters . ....... . . . .. . .. . . . .. . .......... .. ........ . 3-93 Examine the Stresses Acting on the Workstring . ................... . . . . . . 3-95 Examine String Displacements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-100 Review Bending Moments and Shear Stresses ........ . . . .... .. . ....... . . 3- 102 Reviewing Results in 3D Plots .............. .. .... . ............ .. . . . . 3- 103

Predict BHA Build and Drop (Using Bottom Hole Assembly Module). 3-104 Input Analysis Parameters and Review Results ... .. .. .. . ... . .. . . . ....... 3-104 Determine Where BHA Contacts the Well bore . ........ . .... . ....... . ... 3-107 Evaluate Effect of WOB and ROP . ..... . .. . ............... . . ... ...... 3-108

Using Stuck Point Analysis (Using Stuck Pipe Module) ............... .3- 11 1 Input General Analysis Parameters .. . .... .. . . . . .. . .. . ... . .. . . ... . . . . .. Determine the Stuck Point . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Setting and Tripping the Jar . ....... .. .. ......... . .. . .... . ........... Yielding the Pipe . .. . ....... .... .. . .... . .... . . .. ...... ......... . .. Backing Off. ........... . . . ...... . . .. . . ...... .. ..... . ... ....... . ..

iv

3- 111 3-112 3-1 13 3- 114 3-114



Contents

Running Liner ...... . ... .. .. ....... ....... ........ ........... ..... .... 4- 1 Overview ... ....... ............. .............. .................. . ... 4- I Data .................. . . ............. . . ... .......... ... ..... ... ... Workflow ......... ............. ........ . .......................... Workflow Solution .................................................. What Is Cove red ...... . ........... ............... ......... ..........

4- 1 4- 1 4-2 4-2

Input and Review Well Config uration and Analysis Options ... .. . ... .. .. 4-3 Centralizer Placement (Using OptiCemTM Module) ...... .... ..... ... .. . 4-4 Using Bow Centralizers .................... . .. .. ............... . ..... 4-4 Using Rigid Centralizers .................... . ................... . ..... 4-5

In-depth Torque Drag Analysis (Using Torque Drag Module) ........... 4-6 Matching Friction Factors to Actu al Fie ld Data .................... ... . ... . 4-7

Determining Surge and Swab Pressures (Using Surge Module) .... .. ... . 4-8 Input and Rev iew Well C onfiguration and Analysis Options ......... ........ 4-8 Specify the Operation Data ... .................................... . .... 4-8 Analyze Transient Response .................. . .................. ... ... 4-9 Check the Tri pping Schedule ......................................... 4-10 Reciprocating ...... ..... ..................................... . .... 4- I 0

Condition the Well Prior to Cementing (Usi ng H ydraulics Module) . . .. . 4- 11

Running Liner Solution . ................... ... ......................

5-J

O verview ...................................................... . .... 5- 1 Input and Review Well Configuration and Analys is Options ..... .... .. .. 5-2 Centralizer Placement (Using OptiCemTMModule) ............ ......... 5-3 Using Bow Centralizers ....... ...... ........ .... ......... .. ... . . ... .. 5-3 Using Rigid Central izers . ............................................. 5-8

In-depth To rq ue Drag Analysis (Usi ng Torque Drag Module) .......... 5-12 Mate hi ng Friction Factors to Actual Field Data. . . . . . . . . . . . . . . . . . . . . . . . . . . 5- l 8

Determining Surge and Swab Pressures (Using Surge Module) .... ... .. 5-23 WELLPLAN™ Software Release 5000.1.10 Training Manual


v

Contents

Input and Review Well Configuration and Analysis Options .... . . . .... . ... . Determine Surge and Swab Pressures ... .. . . ...... . .. . .. .. . . ..... . . . ... Check the Tripping Schedule .......... . . .. ... . . . ... . .... ..... ....... . Reciprocating . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

5-23 5-26 5-36 5-4 l

Condition the Well Prior to Cementing (Using Hydraulics Module) ... . . 5-43

Cementing the Liner .... ... .. .. . .. ... .... . ..... . .. .. .. .. ...... .. .....

6- t

Overview .... . ................................................. . .. . . 6-1 Data . . ... .. .. . . . ... .. . .. ........ .. Workflow . . . . . . . . . . . . . . . . . . . . . . . . . Worktlow Solution . .. .. . . . . ... . . . ... What Is Covered ... . ... . ... ... . . ... .

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

6-1 6- I 6-2 6-2

Open the Case . . .. . . .. . . . ... .... . . . .... . . . . .. . .. . . . ... . . . . . . . .. . . .... 6-3 Input and Review Wellbore Data . .. .. . ... . . . ..... ....... . . ... ... . ..... 6-4 Review Hole Section, String, and Wellpath Data .. . . .... .. .. . . . ...... . .. .. . Define Cement Slurries and Spacers . . . .. ... . .......... ... .. . ... . ...... . Review Pore Pressure and Fracture Grad ient Data . ...... . ..... . ......... . .. Review or Input Geothermal Gradient Data . .... ... .... . . . . . .... . ... .. . ... Review or Input Circulating System Data .. . . . .... .. . . .. .. . . . . .. ..... . .. .

6-4 6-4 6-5 6-5 6-5

Centralizer Placement . .. . . . . . ... . .... . . . ...... ... . .... . . .. . .. .. . . . ... 6-6 Specify Depths of Interest. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-6

Estimate Bottomhole Circulating Temperature ..... .... ....... ... . ..... 6-7 Input Cement Job Data ..... . . . ......... . . . ..... . . . ..... . . . .. .. ....... 6-8 Analyze Results . ... .. .. . . . ............... .... .... . . .. .. . ... . . .. . ... 6-10 Review Circu lating Pressures . . . . .. . ... .. . . . ..... . . . .. .. . . . ..... ... . . . Review Downhole Pressure Profiles . . . . . ...... . . . ... . .. . ....... .. ..... . Review Density and Hydrostatic Profiles . . ...... . ...... . ... .. ... . ....... Compare Rates In and Out .. . .. . . . .. .. .. . . . .... .. . . ..... . . .. .. . ...... Review Wellhead and Surface Pressures ... . . . ......... .. .... . .. .. ...... Review Hookloads . . . . . . .. . .... . .... . ...... . . . . .... . ... .... ... . . . .. Use the Flui d An imation to Analyze Job Parameters ... . . .. . . .. . . . . . . . . . . .. Review Hole Cleaning .. . . . ..... . . ... .. . .. . ......... . .... ..... ......

vi

6-10 6- 1.0 6-10 6-10 6- l I 6-1 l 6- 1 l 6-12

WELLPLA N ™ Software Release 5000.1.10 Training Manual


Contents

Fine-tune the Job. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6- 13 Re-exami ne ECDs . . . ... . . . .... . . . .... . . . . . .. .. . . . . ..... .... . .... 6- 13 Re-examine Fluid Tops .......... .. . ........ .. . . . . ... . ... . ..... . .. 6-1 3

Cementing the Liner Solution . .. ............ . .. . .. ....... . ... .. . . . . 7- t Overview . . ..... .............. . ..... . .. . . . .. ... . .... . ... . .... . .. . . .. 7-1 Open the Case . . ....... . . . .. . .. .. . . .. ..... . ......... . .... .... . . . . . ... 7-2 Input and Review Wellbore Data .. . . . . . .. . . . ... . ... . ... .. .. . .... .. .. .. 7-3 Review Hole Section, String, and Wellpath Data .. . ..... . . . . . . .. .. . . .. . . . . . Defi ne Cement Slurries and Spacers . . ... .. .... . ... . ... . ... .. .. ... . ... . . Review Pore Pressure and Fracture Gradient Data . . . ............. . . .. .. .. . . Review or Input Geothermal Gradient Data . .. . . . . . . .... .. ... . ............ Review or Input Circulating System Data ... .. .. ........... . ... . .........

7-3 7-6 7-6 7-7 7-8

Centralizer Placement .... . .. . .. .. . . . . . .. . . . ... . ... . ... .. .. . .... .. . . .. 7-9 Speci fy Depths of Interest. . .... . .. . .. .... . ..... . .................... . 7- 10

Estimate Bottomhole Circulating Temperature ................ ... .. . . . 7- 11 Input Cement Job Data ..... . . . . . .... . .... .. ... .. . ... . . . . .. .. . . ...... 7- 13 Analyze Results . ... ... . . .. . . . . ............... . . . .. . . . .. . .. .... .. ... 7- 18 Review Circulating Pressures . ... . . . ............ . .. .. .... . . ... . . . .. . . . Review Downholc Pressure Profiles ..... . ... ...... .. ... . ... .. ....... . .. Review Density and Hydrostatic Profil es ..... . ... . . ... . . .. . .. ........... Compare Rates Jn and Out ........... .... .. ..... . . . . . . . .... .. . . ...... Review Wellhead and Surface Pressures .. . . . . . ... . ... . .. .. ... . ....... . . Review Hookloads . . .. ... . . . . . . . . . . . . .... .. ..... .... .. .. . ........ . . Use the Fluid Ani mation to Analyze Job Parameters ... . ... . . . . .. .. . . .. . . .. Review Hole Cleaning .. . .. ... .... ... .. .... ... . ... .. . . . . .. .. .. ... . . . Fine-tune the Job ... . ... .. . . . . ....... . .... ......... . ........... .. ... Re-examine ECDs and Fluid Tops ....... . .... . ... .. . . .... .. . . ......

WELLPLAN™ Software Release 5000. 1.10 Training Manual


7- 18 7-20 7-2 1 7-22 7-23 7-24 7-25 7-31 7-34 7-34

vii

Contents

viii

WELLPLAN™ Software Release 5000.1.10 Training Manual 恭贺新禧! http://www.egpet.net ‫ﺷﻛرا ﻟك‬

Chapter

Ii

Getting Started Manual Overview This manual contains one chapter covering basic fu nctionality. The remaining six chapters cover three workflows: Drilling, Running Liner, and Cementing. Each workflow is covered in two chapters, one containing the exercise or worktlow steps, and the other containing the workflow solution. If the exercise steps for a workflow do not provide enough infonnation to complete the step, please refer to the solution in the subsequent chapter for that workflow. An overview of each workflow is contained in the e xercise section pertaining to the workflow.

Data The data used in this exercise is not from an actual well. Although an attempt has been made to use realistic data in the exercise, the intent when creating the data set is to display as much software functionality as possible. Therefore, some data may not be realistic. Please do not let the accuracy of the data overshadow learning the functionality of the software.

WELLPLAN™ Software Release 5000. 1. 10 Training Manual


1-1

Chapter I: Getting Started

Technical Support Information Landmark operates a number of Technical Assistance Centers (TACs) . Additional support is provided through district support offices around the world. If problems cannot be resolved at the district level, Landmark's escalation team is called to resolve your incidents quickly . Support information is always available on the Landmark Graphics Su pport internet page: http://css. lgc.com/CustomerSupport/CustomerSupportHome.jsp

....AA,,,,. HAU.IBURTON Landmark Support Portal $uppor1HrAM

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WELLPLAN™ Software Release 5000.1.10 Training Manual


Chapter

II

Basics Overview Exercise 1: Creating the Data Hierarchy In this exercise, you will create a new company, project, site, well, wellbore, design, and case.

Exercise 2: Specifying Tubular Properties and Working With Catalogs In this exerc ise, you will create a new pipe grade and use it to create a new pipe in an inventory you create. You will also review creating a unit system and importing a catalog.

Exercise 3: Using the Case Menu and Libraries, and Configuring the Workspace This exercise builds on the previous two exercises. Us ing the data hierarchy created in Exercise I, you will specify additional data that defines the case you are analyzing. You will use both the information you entered into the catalog in Exercise 2 and the catalog you imported. This exercise will also familiarize you with using li braries to quickly use predefined strings or fluids. You will also learn how to configure the workspace (tabs) for easily accessing the data and results you need.



1-1

Chapter 1: Basics

Exercise 1: Creating the Data Hierarchy Steps and Questions I. Launch the WELLPLANrn software.

2. Enter your user ID and password on rhe login screen. 3. Create a new company. There is more than one way to do this. 4. Specify Company properties. a) Rename the company "Class." Entry of other company information is not required for this course at this time. b) What would you do if you wanted to prevent editing of the company level data? c) How do you prevent editing of all data associated with the company? 5. Create a new project. a) Name the project "Class Project." Select the UNRESTRICTED Tight Group and use the Mean Sea Level as the System Datum Description. 6. Create a new site. a) Specify general site information. Name the site "Class Site." The Default Site Elevation is 100 feet above Mean Sea Level. Do not apply a tight group (use UNRESTRICTED). Entry of other site information is not required for this course at this time. 7. Create a new well. a) Select the UNRESTRICTED Tight Group Dataum.

1-2



Chapter 1: Basics

b) What unit system will be used for any design or case associated with this well?

I Hint Use the onhne help.

c) Specify the well depth reference, configuration (offshore or onshore), and to view a depiction of the datum . This is a subsea well in 500 ft of water. Specify a 490 ft wellhead elevation. d) What datum will be used for designs associated with this well ?

I

Hint

Use the on line help.

e) Entry of other well information is not required for this course at this time. 8. Create a new wellbore. a) Define general information about the wellbore. Name the wellbore "Class Wellbore." Entry of other wellbore information is not req uired for this course at this time. 9. Create a prototype design for the Class Wellbore wellbore. Name the design "Class Design." 10. Create a case for the Class Design design. Name the case "Class Case." 11. Open the case you created.



1-3

Chapter 1: Basics

Answers I. Launch the WELLPLAN software by selecting Start> Programs> Landmark Engineer's Desktop> WELLPLAN. 2. Enter EDM as the user ID and login screen.

Landmar kl

as the password on the

3. Create a new company. Using Well Explorer, right-click the and select New Company from the menu. Database icon

c·e )

'P WELLPLAN ~

Fiie lllew Tools

II

D~

C~ar

- i:I' Pro

•0

•N

RiQCor + CJ WOfksp +Tubt.W • fj cat~

at:

NIM F
l.kllts Properties...

All:+Enter

Wei Name Well>Dre~

ChariQe ~ory

1-4

Find .••

Ctrl+F

Refresh

F5



Chapter 1: Basics

Alternatively, create a new company by selecting File > New > Company

c~

...

Import

E:a:port PllQe Setup .. .

Print Setup ..•

Exit

Contractor/Rill •

- o- •as;e1' ''' fh C~ -# +

Prodi

CataioQ

Instant C4se

N Llli06i1i60 !Mb

+

O Rll) Contractors CJ Workspoces It• TubUat Pr*'ties

+

fj CataloQs

+

+

4. Specify company properties. a) On the General tab of the Company Properties dialog box , type Class in the Company fi eld in the Details section. 1p1

[RJ

Company Properties

I

General Real rrne Corh;µations Audt Ir-lo

Details Company:

Division:

r

Iaassl ...-~~~~~~~~~~

Company is lod
Passwords

l~ 0«4 j C~ Level l C«lCel



1-5

Chapter 1: Basics

b) To prevent editing of the company-level data, you can set a company-level password by clicking Company Level and specifying a password. You can also check the Company is Locked check box; however, this box will not be password-protected unless you set a company-level password. c) To prevent editing of all data associated wi th the company (projects, sites, wells, wellbores, designs, and cases), cl ick Locked Data to specify a locked data password. 5. Create a new project when prompted or by selecting File> New > Project. a) Use the General tab of the Project Properties dialog box to spec ify project properties. Name the project Class Pr o ject . Select UNRESTRECTED from the Tight Group Name pulldown list in the Security section. Select Mean Sea Level from the System Datum Description pu ll-down list. ~

'P Project Properties Genetal

I Audi: lrfo I

Details

jClass Proiect

Project:

Securty

Tight Group Name:

IU\'RESTIUCTEO

IMean Sea Level

r--

Active IXlt System Project lnts:

r

j(none)

Proiect IS fod
QI(

1-6

Cancel

I

Apply

J



Help

Chapter 1: Basics

6. Create a new site when prompted by clicking Yes. a) Use the General tab of the Site Properties dialog box to specify general site information. Name the site Cl as s S ite . The Default Site Elevation is 1 oo feet above MSL. Do not apply a tight group (select UNRESTRICTED).

I

I

General LocatlOll Audt irlo I

Details

IClass Slte

Site: O.sb1ct:

Block: Default ste Elevation:~ ft above Mean Sea Level Seari;y

TiQht Group Name:

r

jl.NlESTRICTEO

Sle IS locked

Cancel



1-7

Chapter 1: Basics

7. Create a new well when prompted by clicking Yes. a) Use the General tab of the Well Properties dialog box to specify general well information. Name the well Class we l l. Do not use a tight group. Select API from the Well Units pull-down list. Leave the other fields on this tab blank. 1p1

~

Well Proper l ies

I

I

I

General Depth Reference 1.ocat1on Ai.at irlo

I

Details

Wei (Ccmnon): Wel (lCQal):

IClass Wei

..------------------

location Sbinl,;J: U"qJe Wei

Identifier

U.W.I.:

---------~----~~~--~

Type: Wel No.:

Location CO<.rtry:

State/Prov: CO
T!Qht Group Name: jl..N
a

Active Urit System

Wel~s:

......-----3--..

Halards Preserl:

r

Wellislocked

H2S

r

LSA

r

C02

r Cancel

b) API units will be used for any design or case associated with this well.

1-8



Chapter 1: Basics

c) Use the Depth Reference tab of the Well Properties dialog box to specify the well depth reference and configuration (offshore or onshore), and to view a depiction of the datum. This is a subsea well in soo ft of water. Specify a 4 9 o ft wellhead elevation. If" Well Propert ies -

- - --- - - -

-

--

-- -

---

['gJ

- - -

I

General ~h R~ence ] tocabon Audit Info

o.n.n elevabon !lbove: Mean Sea Level

r

2

Corilcpatlon

~

Offshore Wik.er Depth

rsoo--

Del'"'* Oatun ft

(MS\. to Mu
~ SUbsea

Wehad Depth:

~ ft

(from Mean Sea Lavell

- -- -

..'I

Otk.l.fn Elevation: A.- Gap (MSI.):

I

100.0ft 100.00ft

•• Mean Sea Level

Muclne Depth (MSL): .· Mudorle TVO:

soo .OOft 600.00ft

- - · - - -- --- --;::=====::;-- -- :-· OK

I _ C!lll
Apply

~

d) Designs and cases associated with this well will use the datum with the Default check box checked.

WELLPLAN TM Software Release 5000. 1. 10 Training Manual


1-9

Chapter 1: Basics

8. Create a new wellbore when prompted. a) Use the General tab of the Well bore Properties dialog box to define general information about the wellbore. Name the wellbore Cl ass Wellbo r e .

fg)

IJ' Wellbore Properties

I

I

General I R~ Tine Corli\l<.ratiOnS Audl trio ChonQe Hstory

IClas$

Common N.!Jme:

I

Welbore

LeQal Nane:

Bottom Hole l ocation: ST No:

r-

Sldetrack.ITom an ExisttiQ Welboro

ParontWellore:

,..,Not- Tled....,..---------------3-i :::J

TAl"l. Class:

J

Kld
r

Kickoff "'1>:

i - - ft

Welbor& IS lod
OK

Apply

-I

Help

9. Create a design for the Class Wellbore wellbore when prompted. Name the design C l ass Desig n . Indicate the design is a prototype by selecting Prototype from the Phase pull-down list.

IRJ

IP Design Properties

I

General I ~ Wo Change Hstory

I

Detdils

IClass Oesq,I

Design:

Version:

Pl14se:

JPrototype

3 [:j

Effec!lve Date: ~h Reference

lnlormatoo /Default Datum@ 100.0ft Datum Elev~:

.·1AM

Gap (MSL):

• Mean Sea level l>\Jdtne Depth (MSl): • l".udli>e TVD:

100.0ft 100.00ft 500.00't 600.00't

OK

1-10



Chapter 1: Basics

I 0. Create a case for the Class Design design when prompted. Name the case Cla s s Ca s e .

{RJ

IP Case Properties Genet al

jJob

I

I

Contact Audit Irio Ch.¥>oe History

I

Oet.!lils

c..se:

IClas$ c~I ~~~~~~~~~~~~- .

~:

Depth Reference !rlorlndtlOn

!De1au1t Datun@ 100.~t Datum Elevl!ticn:

100.m

Air Gill)

100.00ft

. I

1Mean Sea(MSI.): level

•

Mudline Oe¢i (MSl): • Mudline T'fO:

Or4I Depth Rotn;i:

r

r-

500.00ft

600.00ft

fl

(O$e 1$ locked

OK

(.,..;el

I

Apply

~~

J

11. If the case does not automatically open, you can open it by doubleclicking the case name in Well Explorer.

WELLPLAN™ Software Release 5000.1 .10 Training Manual


1-11

Chapter 1: Basics

Exercise 2: Specifying Tubular Properties and Working With Catalogs Steps and Questions I. Access the Materials spreadsheet. 2. Create a material named "Class Material." This material has the

following properties: • • • • • • • •

Description: Leave blank. Young's Modulus: 30,000,000 psi Poisson's Ratio: 0.3 Density: 490 lbm/ft3 Temperature Deration: Steel Expansion Coefficient: 6.9 E -06 °F Thermal Conductivity (BTU/hft°F): 26.8 Specific Heat Capacity (BTU/hft°F): 0.1 3

3. Access the Grades spreadsheet. 4. Create a pipe grade named "Class Grade." Th is grade has the

fo llowing properties: • • • • •

Section Type: Casi ngffubing Material: Class Material Minimum Yield Strength: 125 kpsi Fatigue Endurance Limit: 25,000 psi UTS: 135 kpsi

5. Create a new Casingffubing catalog. Name the catalog "Class Casing." 6. Open the catalog you created and create a casing with the followi ng properties. If a property is not listed below, leave the entry for that property blank: • • • • •

1-12

Nominal Diameter: 11 3/4 in Nominal Weight: 65 lbs Grade: Class Grade Body OD: 11.75 in Body ID: 10.682 in



Chapter 1: Basics

• • • • • • • • • •

Weight: 65 lbs Pipe Type: Special Drift ID: 10.625 in Burst: 9,940 psi Collapse: 6,540 psi Body Yi eld Strength: 2,352,0 J 0 lbf Linear Capacity: 0.1108 bbl/ft Closed End Displacement: 0. 1341 bbl/ft Average Joint Length: 40.0 ft Wall Thickness: 87.5 %

a) If the Pipe Type is Standard, what casing properties cannot be specified? b) Save and close the catalog. 7. Make a new Units sec and name it "Class Units." (Tools> Unit System) Base the new unit sec on API units. a) Use the psi/ft unit for Mud Weight. b) What is the active unit sys tem ? c) Is the unit for density psi/ft? You can refer to the Fluid Editor (Case > Fluid Editor) to determine what unit is associated with density. d) Activate the API unit set. e) Have the units for mud density changed to ppg? 8. Save the case, but do not close it.



1-13

Chapter 1: Basics

Answers l. Access the Materials spreadsheet by double-clicking Materials in the Well Explorer. You may need to expand the Tubular Properties node. 2. To create a material named Class Ma t er i al, add the new material in the first blank line at the end of the list. If' Material

r

- - - --------- ~ -

-

(Q][EJ

locl
~ Coelfide
6 90

The.-rnol CoMlctlVCy (BIUA>ft'F) Spec:.rl: HMO~ (BT~'F) ,,

26«JOOOO

0 1300

3. Access the Grades spreadsheet by double-clicking Grades in Well Explorer. 4. Create a pipe grade named Class Grade. Add the new grade in the first blank line at the end of the list. It is very important to specify the section type. If not, the grade will not be available to you when you create a new pipe in a catalog later in this exercise. t' Gr•d•

1-14

-



(g rg:

Chapter 1: Basics

5. Using Well Explorer, right-cl ick the Casingffubing catalog and select New from the right-click menu. To create a new catalog: 1. Click on the catalog group (Drilling Tools, Completion Tools, or Wellhead Equipment) in the Well Explorer. For this example, select Drilling Tools. 2.

3.

- /( dass Site ,.. - i Class Well Class Wellbore (S/12 dass Design 0 dassCase Company Ful FeatU'e Oil Co. NeptU'le 0.1 ComP«IY t:i Canada Linlt:ed Tr alnlr19 Company RIQ Contractors Workspaces Tubular Properties

- I..

- 1'

• • • •

Highlight the catalog type in Well Explorer. In this example, Casing/ Tubing is highlighted.

+

+

Right-click the highlighted catalog category and select New from the right-click menu.

fb fb fb fb

0 D

+

rlt:

-

S cat~

- WI

Drilllnc;i Tools

g Accelerators • Im Ad)UStable Near Bl Reamers +

• Q &ts + (g CllSIOQ Serapers

m

+ CamQ Shoes • ~ Camo/Tubino Connectors

+ +

fi) H..-.!.Qiif . .:.;

g

Centrallers

, . , ,. • •• .J ... ... · - ·

4. Specify the name of the new catalog in the Catalog Properties dialog box. 5. Optional: Specify a description of the catalog to help you identify it later. 6. Click OK to create the catalog.

/pf

Catalogs Properties

General

IAudit Info

Details

Paste

Ctrl+V

IBJ

1

Name:

IClass Casing

Description:

j User created cataloQ

r

New... Ins

Locked



1-15

Chapter 1: Basics

7. The new catalog displays in the Well Explorer within the catalog type you selected in Step 2.

OrlnQ Tools Accelerators

+

g

+

(gl

+

Q

+

(!I CaslnQ Scrapers

+

mCasl'lQ/Tl.bfrw;j ConoedOl's

+

Adjust able Near &t Reamers &ts

mCaS1119

Shoes

- ~ CaS1119S/TubS'lgs ~ AP! Casing/T ubinc;J

~---- ~ lifjfjf£1!.I.J

I

•g •g

::::=:~:: :

Ha!iburton Redbook Casing I Halliburton Redhook Cas111Q I Halibl.rton Redbook Casi~ ! Hl!Bb.rlon Redhook Tubir'q I ~ Halibu'ton Redbook Tubing l Q;g Halbxton Redbook Tubir'q I \i;6 H"1ibuton Redbook Tubiig I Centralizers Coiled Tubings

• fg Core Barrels

. m ,,... ...... _. . ,....... , .... .. ..... ..

>

<

6. Using the Well Explorer, double-click the catalog you created to open it. After the catalog is opened, you can specify the new catalog entry. 8~

~

~ Ca-

Dewill
Model

N""'"'61 Diamo.I.,

11 75

Nomnal

We9>1

&5

Gtodo

00 (l!'I)

ClasoG1odo

11 750

10

1...1 10682

Woigtll

(ppJj

Pipe Type

65.00 Special

DnttlD

linl 10.625

. . f=r=~i (pstJ

!Poi)

9940.00

6&CQ.OO

(pa)

iL(

_!_

a) If the Pipe Type is Standard, the Collapse Resistance and Body Yield Strength will be calculated based on the grade and associated material of the casing. b) Save and close the catalog using the catalog node rightclick menu.

1-16

WELLPLAN™ Software Release 5000.1 . 10 Training Manual


Chapter 1: Basics

7.

Use Tools> Unit System. Base the new unit sec on API units. Notice that the active Unit Set name is displayed in the Status Bar. ~

IP Unit Systems [ditor Artrte Vlewt'IQ IN System:

API

ISI

jAPI""

API - us Suvey Feet

I

f'\ted AP! Ohld API

Class

U1t

:m•f".,., bick New to Angles

ArruM Velocity Arel>, TFA Alilluth, Vettlcai Section Ar'(je, BeerlnQ

Bi Diameter Cement Yoeld

.'"

ft/rrln

reate a new nit system.

In

ft>/sk9'1

Coefficient rJ Friction

no unM:s

Component L~h Oej:>th, Distances, He!Qhts

ft ft

o.erneters

In

~Severty

.

EQl.ivalent fl\Jd W"lt

FamReadrqs Flow RMe (Cemott) Flow RMe (MUd)

•1 10Clt PllO

~Ce/length GasV~

(gJ

'P1 New Unit System

Select API from the Name: Iaass ttts Template pull-down list to base the new unit set Descripboo: on AP I units. - -_ . Template: IAP1 OK



1-17

Chapter 1: Basics

a) Use the psi/ft unit for Mud Weight. Select Mud Weight from the list of unit types and then select the unit you want to use for that unit type.

(8)

If>' Unit Systems £ditor

...,

gram

oal/sk94

r

..bf/lenottl i

' Normaliled Force Percent Per~

% md

!'tie 5f>eed (Sts'oe)

ft/s

Prec...on

Expo(t

~Speed

ftJroo

Import

Power

hp hp[n> psi/ft psi

New ...

Power/Ar~

PresStXe Gradient Pressure Rate ot Penetration

revs

Revolutlons

... .... 1.w ....... ~• ••

OK

ft/hr

J

Edt ...

...,

Delete

~_J

b) The active unit system is Class Units. You can tell what unit system is active by referring to the Active Viewing Unit System pull-down list in the Unit Systems Editor. The active unit system is also displayed in the Status Bar.

1-18



Chapter 1: Basics

c) Refer to the Fluid Editor (Case> Fluid Editor) to determine what unit is associated with density. IP fluid [ditor

tE}

-

I New I 1.tirarvl

Activate

1 f>\Jd Density

F!uod # 1

psi/ft

j.Hl6

R~Model

lllngMm Plastic

_:J

R~Oata

IPV and yp

Plastic Viscosity

~~cp

3

T""llCI'atLl'e

Yield!>ort

~ llli/IOO't>

Fann Data

Save RPMs as Oefaull:

i...

Speed 000211

(rpm)

-1--+,.....,...,,.f-__,+,._.:;..'-t---t--

I

Dial

rJ

600

~

300

!

0.0010

o~~l----.-~-r--.-~1~,_. . . ,~,. . . . . .,.1 100

200

300

400

600

l!OO

Sl>ur Fbr•(l/uc)

QI;

I__:_ance1 J____.

_ Heli> __

d) Activate the API unit system using Tools> Unit System. Select API using the Active Viewing Unit System pull-down list. ~

IP Unit Systems Cditor

a

Active Viewinq lkll System: IAPI

AP!

1s1

1 AP! .us n~im·• • • • • • • • API • US SLl'vey Feet

Class lk1is fllxed AP! Ol'ieldAPI

fJ.r9es

l!rnkr Velocity />lea, TFA Azinuth, l/ertlcal Section M9e, BeatinQ Bit Diamete< Cement Yield Coefficient of Frittion

.

Component Length Depth, Distances, He~s Diameters OoQleo Severity t:qUvalent f>\Jd w~ Fam Re&dlni)s Flow Rate (Cement) Flow Rate (Mud) Force/Leo;ith GasVoUr.M

ft ft

--- -

ft/mln in>

on ft>/sk91

no units In 0

/IOO't

~

New...

bbl/rm IP"

______________



ti/ft Mscf

_,

1-19

Chapter 1: Basics

e) Refer back to the Fluid Editor (Case> Fluid Editor) and note that the units are now ppg. 1P 1

Fluid fdilor

I New I lheryj

Activate

FUd 11

ja.so

l'MJOensty

PPQ

Rheolo
1~Plastlc

Rheolo
IPV and YI'

..:.J

~ cp~ I•2.000 lbf/loctt>

T~ature

Plastic Viscosity Yield Pttt

rg)

RudPlot

3

FannO<>to Save RPMs os Oefd

Speed (rpm) 600 300

00020

I Dial

1·1

0.11010

100

200

300

..,

600

000

Sti.or Rat (1/ffo)

OK

J

Cao:
J_ __..

8. Save the case by selecting either File > Save As or File > Save.

1-20



Chapter 1: Basics

Exercise 3: Using the Case Menu and Libraries, and Configuring the Workspace Steps and Questions Using the Case Menu 1. Define the hole section, including the last casing, liner, and the open hole section. (Case> Hole Section Editor)

•

The hole section depth is 17 ,968 ft.

•

Use 12,534 ft of A Pl 13 5/8", 88.2 lb/ft, Q-125 casing with 17 .5" effective hole diameter. (Effective hole diameter is only used in the OptiCemTM module for cementing analysis.)

•

Enter 3,597 ft of 11 3/4'', 65 ppf, "Class Grade" liner. ("Class Grade" is the grade of the pipe. You must select this casing from the catalog you created in the last exercise.) Use Casing as the section type for liners. The effective hole diameter is 14.75".

•

There is l ,837 ft of 12 1/4" open hole. The open hole is gauge.

•

Use .2 friction factor in cased hole and .3 in open hole.

2. Define a simple drill string to become familiar with using the Case > String Editor.

•

String Depth: 17,968 ft

•

Drill Pipe: API Drill Pipe Catalog, 17 ,045 ft, DP 5 in, 19 .50 ppf, G, NC50(XH), P

•

Heavy Weight: System Heavy Weight Catalog, 60 ft, HW Grant Prideco, 5 in, 49.7 ppf

•

Jar: System Jar Catalog, 33 ft, Dailey Mechanical 6 1/4 "OD, 2.25" ID

•

Heavy Weight: System Heavy Weight Catalog, 300 ft, HW Grant Prideco, 5 in, 49.7 ppf



1-21

Chapter 1: Basics

•

Drill Collar: API Drill Collar Catalog, DC, 390 ft, 8" X 2.5", 7 H-90

•

Stabilizer: System Stabilizer Catalog, 5 ft, IBS , 10 5/8" FG, 8 x 2.5"

•

Drill Collar: API Drill Collar Catalog, DC, 30 ft, 8" X 2.5", 7 H-90

•

Stabilizer: System Stabilizer Catalog, 5 ft, TBS, I0 5/8" FG, 8 x 2.5"

•

Drill Collar (Non-mag): API Drill Collar Catalog, 31 ft, NOC 8" X 2.5", 7 H-90

•

Stabilizer: System Stabilizer Catalog, 5 ft, IBS , 10 5/8" FG, 8 x 2.5"

•

MWD: System MWD Catalog, 30 ft, MWD 8, 8 x 2.5 in

•

Mud Motor: System Mud Motor Catalog, 30 ft, BHM 8, 8 x 2.5 in

•

Sub: System Sub Catalog, 3 ft, BS 6, 6 x 2 1/2 in

•

Bit: Security DBS, 10.625, Tri-Cone Bit, XL20, 5 l 7X

3. Import a catalog containing a bi-center bit using the file Class Bits.cat.xml. C hange the bit in the string to the bi-center bit in the catalog you imported. 4. Import the Wellpath data using the file WPR5000_ TrainingWellpath.txt. Your instructor will tell you where the file is. The column order and units are: MD (ft), Inc (deg), and Az (deg). Review the wellpath data using Case> Wellpath > Wellpath Editor. Note It is important that you correctly specify column order and units.

1-22



Chapter 1: Basics

5. Create a fluid using the following properties. Activate the fluid after you create it. In this example, PY and YP are specified. If you have access to Fann data, it can be specified instead of PY and YP. Use the following properties: • •

• • •

Name: 15. l ppg OBM Density: 15. l ppg at 70° F PV: 24 cp at 70° F YP: 12 lbf/I 00ft2 at 70 °F Rheological Model: Bingham Plastic

6. Copy all pore pressure and fracture pressure from the file WPPoreFrac.xls. Paste the pore pressure data into the Case> Pore Pressure and the fracture gradient data into the Case > Fracture Gradient. a) How is the first row of the Case > Pore Pressure spreadsheet calculated? b) Depth is always required for entry into either of these

spreadsheets. Why is it necessary to specify either EMW o r pressure for entry or copy into these spreadsheets? 7. Specify the geothermal gradient. The surface ambient temperature is 80° F, the mudline temperature is 40° F, and the temperature at TD is 279.5° F. What is the geothermal gradient?

8. Specify mud pump and other circulating system data. a) The surface equipment rated working pressure is 6,000 psi, the

surface pressure loss is 100 psi, and the surface equipment type is IADC. b) Select the follow ing two pumps from the catalog. Activate only the A 1400PT pump. Make

Description

Type

Liner ID

Rod OD

Efficiency

Oilwell

Al400PT

Triplex

5"

none

100

Oilwell

A l700PT

Triplex

6.5"

none

100



1-23

Chapter 1: Basics

Using Libraries 9. Export the string you created by clicking Export on the Case> String Editor. Name the string' 10.625" BHA.' I 0. Export the fluid titl ed " 15.1 ppg OBM" by clicking the Library

button in the Fluid Editor. You could change the name if you wished, but, for this exercise, you will not change the name. 11. Create a new case by right-clicking the Database icon in the Well

Explorer and selecting Instant Case from the right-click menu. Include this case in the Class company. Create new names for the remaining hierarchical levels. The well is subsea, in 328 ft of water, with a wellhead depth of 323 ft, and a default site elevation of 100 ft. 12. Open the case you created in the previous step, if it is not already opened. 13. Open the Case > String Editor. Notice there is no string data in String Editor. Import the 10.625" BUA string you created from the library. Set stri ng depth to 17 ,950 ft. 14. Open the Case> Fluid Editor. Notice there is no fluid data in the Fluid Editor. Import the 15.1 ppg OBM fluid you created from the library. 15. Assume you want to transfer your libraries to another computer, or you want to share your libraries with another person. Create a library transfer fil e.

Configuring the Workspace 16. Continue to use the case you created in Step 11 (using the Instant Case option). 17. Create the following tabs by renaming or creating additional tabs. Use window splitters near the scroll bars to create window panes.

a) Create a tab titled Sc he mat i c . On that tab, put the Well Schematic-Full String-not to scale. b) Create a tab titled Editor s . Create two horizontal panes on that tab. Open the Hole Section Editor in one pane and the String Editor in the other pane.

1-24



Chapter 1: Basics

c) Create a tab titled ~vellpath . Open the Wellpath Editor in this tab. d) Create a tab titled Plots. Open the Inclination plot in this tab. 18. To illustrate the Copy/Paste functionality between cases and designs, you will copy the hole section from the Class Case case in the Class Project you worked with earli er in this exercise. a) Jn the Well Explorer, highlight the Class Case in the Class Project. What items are linked at the case level? b) In the Associated Data Viewer (located at the bottom of Well Explorer), right-click the Hole Section entry and select Copy. c) In the Well Explorer, right-click the case you created in Step 11 and select Paste from the right-click menu. d) Notice the Associated Data Viewer indicates the hole section depth has changed. e) Notice the Case> Hole Section Editor displays the hole section data. 19. Copy the wellpath from the Class Design design in the Class Project project to the design you created in Step 11. Notice the wellpath is now displayed on the Wellpath tab and the inclination is displayed on the Plots tab. 20. Using the Associated Data Viewer, determine what data is linked at

various hierarchy levels (design, case, wellbore, and so on). a) What data is shown to be linked at the design level? b) What data is shown to be linked at the case level? c) What data is shown to be linked at the wellbore level? 21. Save the tab configuration as User Defined Workspace . Name the workspace C l ass Workspace . Notice the workspace you created is now listed as User Defined Workspace in Well Explorer. 22. Save and close the case. 23. Re-open the case. What tabs are displayed and why?



1-25

Chapter 1: Basics

24. You can export your workspaces if you want to share them with another person. Export the Class Workspace workspace you created. 25. In the Well Explorer, notice the node titled "System Workspaces." System Workspaces are installed with the software. Can you modify a System Workspace? Review the tab configurations associated with each System Workspace. 26. Module Workspaces arc a convenient way to use the same tab configuration every ti me you use an analysis module, regardless of the case you are analyzing. To illustrate, continue to use the case you created in Step 11. a) Activate the Torque Drag Analysis module. b) Apply the Torque Drag Analysis System Workspace. Did the tabs change? c) Save this as the default workspace for all Torque Drag analysis. d) Open the Class Case case in the Class Project project, if it isn't already opened. e) Activate the Torque Drag Analysis module and notice the tab configuration. What tab confi guration is used? f) Assume you do not want to use the Torque Drag default

workspace configuration; how can you use the Class Workspace you created?

Configuring and Using Plots 27. This exercise step demonstra tes the Freeze Line. Continue to use the case you created in Step 11. a) Freeze the curve on the Inclination plot using the Plots tab. Specify the color of the freeze line to green, change the width to 3, and change the name of the curve. b) Using the Wellpath tab, change the inclination near 2500 ft to 50°. Notice the two curves visible at this depth on the Inclination plot.

1-26



Chapter 1: Basics

c) Right-click the curve with the 50° inclination and select Hide Line. What happened to the line? d) Add a Halliburton® logo as a background logo to the plot. Your instructor can tell you the location of the file. 28. Generate a survey Vertical Section plot. Use the Plot tab. a) Change the width of the data curve (vertical section line) on the Vertical Section plot to 3. Hint Righl-click the curve and use the Line Properties oplion of the rightclick menu.

b) Activate the Graphics toolbar by clicking anywhere on the plot. c) Use the Data Reader (third button from the left on the Graphics toolbar) to determine the vertical section at TD. What is it? d) View X/Y coordinate data for the plot and then return to the plot view. 29. Click the Properties button to open the Properties dialog box. The following questions highlight the functionality of these tabs. Hint To easily view the changes to the plot, move the Properties dialog box so that the plot is visible. Do not forget to click Apply to implement changes.

a) Using the Axis tab, draw the X axis where Y =0 and remove the tick marks from the Y axis. b) Using the General/Grid tab, remove the grid lines from the plot. c) Using the Labels tab, change the Y axis label to ''True Vertical Depth." d) Using the Font tab, change the axis labels to green and italic. e) Using the Markers tab, display data markers every 50 data points.



1-27

Chapter 1: Basics

I) Using the Legend tab, tum off the legend.

g) Click OK and notice the changes to the plot. 30. Save and close this case. 31. Export this case at the company leve l using the fi le name of your choice.

1-28



)

Chapter 1: Basics

Answers Using the Case Menu

I. Use Case> Hole Section Editor. Hole S~IOI Ediol

Hole Name

jHole SectlOl'I

Hole SectlOn De¢> (MO)

1179680

SecllOl'I Type

!Asng

2

qopenHole

Elfecbve

Shoe Ler>!l(h (fl]

(ft)

1253-4 0 16131 0 17968 0

--

I

p- Addot!OMI Cok.rrrn

It

Meas1J1ed Depth

~Casng

I~ Hole Section

12534 oo 359700 183100

L......

o_:

10 (tnl

01,l (tn)

17968.0 16131 0

12.375 10.682 12.250

12250 10.625

Meatl.fed

Tapeied?

r r r r

Hole O'j;iei

17500 14 750 12250

Fncloon Factor

Lineai Uipact,y {bbl/fl)

025

01489 01108

030

01458

E>
Item DesaipOOn 13 5181'1. 88-2 pp/, Q-125. 11 75 n, 65 pp/, H2S·9J

boo

2. Use Case> String Editor. SmglSmgN~ Smg"'4D!

1•79680 sec1 ... 1~

Dr•Pw H...,,Ww;Jt J..

H_,.w.qw OrlC.

s......

Orl C... s~

o.. Colar s~

M'WO

lbal)I

I

E- t II

Spedr hop1o8-

I.er¢

(ftJ

:3

l~Smol

M...,..ed

DOl>Ch ~)

1104500 6000 3300

moo

39000 5.00 30.00 5 00 31 00 500 3000 3000 100 100

17045.0

inoso 1n380 174360

17828.0 17833.0 17963.0 17868.0 17899 0

00 (nJ 5000 5000 6250 5000 8000 8000 8000 8000 8000

1~.o

aooo

17934.0

8000

17964 0

8000

179670

6.000 10625

179680

'"""" 10

(nJ '211i 3000 2250 3000 2500 2.500 2500 2.500 2500 2500 2500 2500 2400

WELLPLAN ™ Software Release 5000.1.1 0 Tra ining Manual


21 92 Ori Poe 5 "' 19.SD ll!ll. G NC5Q?Oi ~ P 41'0 Hw..,. w.qw Ori ,,.,. Gran! Pndoco. 5 n. 49. 70 ppf 9Q98 Mec:henicol J• o-.,Moch. 61/4 n 49 70 HN\O)l 'Y/t9'1 Ori P'* G1an1 Pftdoc:t>. 5 n. 49 70 ppl 15433 Dr1Color 8 n 2 112n7 H-9Q 1506 tn1egit1BladoSl.._,10518"FG 8"2112n 154 33 DrfColor8"'. 2112n. 7H-!Q 1S4 36 lnlegtl Blade St..... 10 518'' FG. 8 "2112 in 15211i Non Mag Orf Colar 8 "· 2112 n. 7H·!D 154 36 ll'llegr.. Bl.ode Sl..,.,Ol 10 518'' FCi. 8 "2 1/2in 154 36 M'WO Tocl8 , S.2 112n 15436 BlntHOUMg8 , 8"21/2n 79518•Slb66"21/2n 166 00 Ti.Cone 8~. Jw16. 0 589 in'

1-2 9

Chapter 1: Basics

3. Right-click the Catalog node in Well Explorer and select Import Catalog from the right-click menu. Use the Import Catalog dialog box to navigate to the correct folder, then select the file you want to import. After you import the catalog, it will be located under the catalog category titled " Bits" because it is a bit catalog. 1. Click an inactive (gray) cell in the row defining the bit in the Case > String Editor. 2.

Access String> Catalog using the main menu .

3.

Select the catalog you imported by selecting Class Bits from the pull-down list.

4.

1p1

fZ;j Ale Edt MOO.Jles Case View Composer Tools

WI Window

Help

.,,:.t. Data ..•

@~

BIT Caralog

ICJM• a~.

~~

I

:.:.!

(l(t'HI: St Sect.llty OBS

WJCCode

ll'P"

Model

II!

Highlight the bit you want to use. (In th is example there is only one, so it is automatically highlighted.)

I

DK

I

C&'leel

J

~eU

5. Click OK and the selected bit will replace the bit in the Case> String Editor.

•1ngEditor

--

StMQI~~'°"

SttngNarne

rlAss-emb_.,.,ly---- - -- - -- - - - --

Slting (MD~

117968.0

Section Type Dnl~

Heavy \\/etglt Jar

Hea..,,weq.t OrilCoLlr Stabili2.. D1i1 Colar

Stoboi.?ei ' DrilC:. Stdzei

M'WO Mud Motor

Sub B~

1-30

ft

Sgedy.

ITop to Bottom Lon¢i (It)

iJ De;.lh (It

170-44.50

60.00 33.00 30000 ~. 00

5.00 :ll.00 5.00 31.00 5.00 30.00 30.00 3.00 1.50

E>
Import Suing

Measured

OD (in)

17044.5 Jn04.5 17i37 5 17437.5 17827.5 178325 17862.5 17867.5 178985

5.000 5.000 6.250

17933.5 17963.5 17966.5 17968.0

aooo aooo

1nms

----

Lbary

5.000 8000 8000

aooo

9000 8000 8000

6.000

1.--t 10 (in)

4.276 3.000

2.250 ~000

2.500 2.500 2.500 2.500 2.500 2.500 2.500 2.500 2.400

i0.625

We'qi.

(ppl)

21 .92 O,.Pipe 5 in. 19.50ppl. G. NCSC»Cenleied B~. 3.10. 5x10. 0.614 rl

WELLPLAN TMSoftware Release 5000.1.10 Training Manual


Item Oescriplion

Chapter 1: Basics

4. Use File > Import> Wellpath File to import the file WPR5000_TrainingWelpath.txt. Review the wellpath data using the Case > Wellpath > Wellpath Editor.

It is important that you correctly specify column order and units.

Urit

Cok.rnn Ordef MD: Inc:

Az:.

11

~

MD

ltt

12 13

~

Inc:

Ideg

.::::.1 ~

:o:J

Az.

' deg

3

ligs\hz15239\Desktop\WPA5000_Trainino\.Velp

OK

I Browse

C&lcel

Help

5. Enter mud properties in the Fluid Editor. Click New to enter data for a new fluid (Case> Fluid Editor). After you have finished inputting fluid properties, click Activate to indicate you want this fluid used in the analysis.

Click New to enter a new fluid.

[El

'P' Fluid [ ditor

~~

~

Mud Density

j1s.10

Fluid If I

Rheology Model

IBingham Plastic

15. I PP9 OflM

P.heoloQY Data

IPV and yp

Lilnry

After you activate the fluid, a tear-drop symbol is placed next to the active fluid. There can only be one active fluid .

ppg

~=

T~ature

Plastic V!sccmt:y Yield Peri

112.000

lbf/IOOfP

Fluid Plot

Fam Data

_ ___J Speed (rpm)

Dial

rl

600 300

100

300 «>o Shur Rate (l/uc)

200

__ OK~ _

Cancel



j

~

Apply

eoo

~-' 1-31

Chapter 1: Basics

6. Copy all pore pressure and fracture pressure from the file WPPoreFrac.xls. Use Ctrl-C and Ctrl-V to copy and paste the data. In Excel, select the columns you want to copy and use Ctrl-C. In the WELLPLAN software, high light the second row (because it is the first empty row in the spreadsheet) and use Ctrl-V to paste the data. Paste the pore pressure data into Case > Pore Pressure and the fracture gradient data into Case > Fracture Gradient. Because these spreadsheets contain no data except for the first calculated row of data, you can either Overwrite or Append the data into these spreadsheets.

0 In Excel, select the columns you want to copy and use Ctrl-C to copy the data to the clipboard.

1 de th fl

2 - - 4-'-3-M

depth ft

1476 1004 1969

m7

B 21 B 35 8 41 8 49

1476 1804 1969 2297

11 .24 11.4 11 .56

3181

8.81

3181

3279 3344 3764 4505 4624 4712 5100 5344

8.82 8.82 8 87 8.92 9 29 9.57 9 69 1017

3279 3344 3764

12.3 12.45 12.6 12.75 12.95

5400

10.64

5400

56aJ

11 11 9 27 9 29 96

1c •

Highlight the row where you want to begin the copy. I n this

t

~ <*¥''

•

4505

4624 4712 5108 5344

6475 7355 7798 8281 8767 9259 9756

1079 10 99 11 29 11 .58

10254

9.86

5600 5801 6475 7355 77'38 8281 8767 9259 9756 10254

10504

10

10504

10753

14.63

10753

11-,,:;1

11 AA

11?1;1

5801

?A

E F frac p psi frac ppg

10.2

•1 \Sheen,( Sheet2

Ve
i

Sheet3 /

11

9

13.25

13.42 13.51

13.85 14.19 14.53

13.22 13.24

13.47 13.9 14.41 14.46 14.67 14.88

17 17 17.82

1F'

I ~0,:,)0 I [:) I 1 example, highlight the___... k1~~~~~~~~~~~~~~~~~i~~~~~~~~~~~~~~~~223 i~•;;~~~~~~~~~~~;;;;11 first empty row. Click I'::' 600 0

on the row number to highlight the row. Click Ctrl-V to paste the data into the spreadsheet .

1-32

WELLPLAN™ Software Release 5000.1. 10 Training Manual


Chapter 1: Basics

Indicate whether you want to Overwrite existing data or Append data by clicking the appropriate button. In this example, either button will work.

1p1

[E)

Paste

Please select one cJ the folowlno.

Overwrto wl overwrto the Sll'oadsheet exdudno

the 1st row Append Wll append to the bottom cJ the Sll'eadsheet Abort wll not paste any data

1·0verwrteJI

Append

Abort

a) The first row of this spreadsheet is automaticall y calculated from the data on the Well Properties> Depth Reference. b) Entry of either EMW or pressure is required. The other value will be calculated. 7. Use Case> Geothermal Gradient. The gradient is calculated based on the supplied temperature data.

I

st.Yldard Additional Piot

:oooo l•ooo

'F 'f

T ~ab.re at Wei TVD

r. Te!Tl)et!ltl.re@ j175S3.6

OK

ft

j279.5C1

'f

11.41

'F/ 100ft

Cancel



1-33

Chapter 1: Basics

8. Use Case >Circulating System. a)

1p1

Circulatin~ S~tem

~

I

51.rface E~ J Mud Punps lv\Jd Pls + Envl'OMleflt

J

Surface EQUIPmeOt Rated Worbng Pressure:

16000.00

psi

r.

5pecfy Pressure loss

1 100.00

psi

r

C!llculate Pressure loss

l1AOC

Surface Equipment Type:

3

Surface EQIJpment IR!ta

r

r r

Cancel

J

Apply

Het;>

J

b) Click Add

(gJ From Catalog to

'1' Circulaling System

~~.: (%)

· I =•

~ff~ Cat.ioc,

I

~------.,H

f.!pn)

t<

I

j 1-34



select a mud pump from the catalog .

Chapter 1: Basics

Double-click to select the Make, Description, Type , Liner ID, Rod OD, and Efficiency.

Select the System Pumps catalog.

OK

Help

r8'.J

'I" Circuldling System

Click the Active check box to check or uncheck it. Check only the Oilwell H01400-PT 5" Liner pump to make it the only active pump.

)

Concel



1-35

Chapter 1: Basics

Using Libraries 9. Export the string you created by clicking Export on the Case> String Editor. Name the string 10 . 625 " BHA. Click Export to export the string to a library.

String lrit~at.oo StnngName !Assembly String Qepth J17968.0 Section Type Drill Pipe Heavy Weight Jai Heavy Weiglil Drill Collar Stabizer Dril Coftar Stabilizer Oril Collar Stabizer M\\IO Mud MotOI

Sub Bil

llxary

Export

It

SJ;!eClly:

ITop to Bottom

Length

De¢1

rt)

(fl)

17044.50 60.00 33.00 300.00 390.00 5.00 30.00 5.00 31.00 5.00 30.00 30.00 3.00 1.50

17044.5 17104.5 17137.5 17437.5 17827.5 17832.5 17862.5 17867.5 17898.5 17903.5 17933.5 17963.5 17966.5 17968.0

OD (in) 5.000 5.000

&250 5.000 B.000 8.000 8.000 8.000 8.000 8.000 8.000 8.000 6.000 10.625

1p1

Click Yes to save the case before you add the string to the library.

1-36

..:J

Copy String

ID (in) 4.276 3.000 2.250 3.000 2.500 2.500 2.500 2.500 2.500 2.500 2.500 2.500 2.400

Weigit (ppl)

21.92 4S.70 90.88 49.70 154.33 154.36 154.33 154.36 152.76 154.36 154.36 154.36 79.51 150.00

WfLLPLAN 5000. 1

J

_IMPOI~

Item Description Drill Pipe 5 in, 19.50 ppl, G, NCSO(XHL P Heavy W~ Oral Pipe Grant Prideco. 5 in Mechanical Jar Oaiey Mech.. 6114 in Heavy Weight Drill Pipe Grart Prideco. 5 in Oril Colal Bin, 2 112 in, 7 H·90 Integral Blade Stabiizer 10 518" FG. 8 x21 Drill Calaf 8 in. 2 1/ 2 in. 7 H·90 Integral Blade Stabilizer 10 5/8" FG. 8 x2 1 Non·Mao Drill Collar 8 in. 2112 in. 7 H·OO Integral Blade Stabilizer 10 518" FG. 8 x2 1 MWD Tool 8 , 8 x2 1/2 in Bent Hous119 8 • 8 x2 1/2 in Bit Sub 6, 6 x2 1/2 in Bi·Centered Bit. Ox16. 0.614 in1

"x

This requres a save to be done. woUd you li


Chapter 1: Basics

Specify the name you want to give the string. You will use this name to identify the string in the library.

(8)

'P' Export Assembly String To l.ibrary

~N.ne j10.625"BHA

Export

Help

Click Export to make a copy of the string in the library using the assembly name you provided.

'To move lbaiies between dalc!lbMet. use lmpo1t/E>


1-37

Chapter 1: Basics

10. Export the fluid you created by clicking Library on the Case> Fluid Editor. Highlight the fluid you want to move to the library. In this example, highlight 15.1 ppg OBM. Click the left-facing arrow to copy the fluid to the library. The fluid will have the same name in the library as it did in the Fluid Editor. You could change the name if you wished, but, for this exercise, you will not change the name.

i:,. Fiuid Editor

- ---

export a copy of a -t-t--No....-t•

fluid to the fluid library.

Llbrarj

Activate

15.l ppgOBM Fluid #I

I1s. 10

I Mud Density

ppg

Rheolo
1~1'tastic

..:J

Rheology Data

IPV and VP

3

Temperature

170.00

Of

PIMtlc Vlsc~y

121 .00

cp

Y'ield Point

I12.000

tif/ I oo.

Fluid Plot

Fam Data

Slier

'0' 8

.,~

0 .0020

~

0.00 10

~ :;;

54ve RPMs as Defid: Speed (rpm) 600

:m

0 .0000

100

200 300 400 Shur R
Cancel

1-38

600

WO

_j ____, __Heir:> _ __.



-[8)

--- ---- - - - - - - - - - -

Click Library to

I

Dial (•)

Chapter 1: Basics

-

-

-- -

. -

-

Import I Export fluids

lpl

Library Fluids

WeMbore FUls

C8J

OK He!p

Highlight the name of the fluid that you want to copy to the library. Click the leftfacing arrow to copy the fluid to the library.

Selected Lbr ary Fluid

__

_J

Density

I

r

Selected Wellbore Fluid

Delete

PPo

Density

r

Type

Type

Base Type

Base Type

Base Flid

Base Fluid

Model

Model

Data

Data

J

I

Renane

PPo

r-

*To move Libraries between databases, use Import/Export on the root node of the Wei

WELLPLAN TM Software Release 5000.1 . 10 Training Manual


1-39

)

Chapter 1: Basics

Import I

Ip!

The fluid is now in the Library Fluids list.

IBJ

Expor~Flulds Welbore FIOOs

IS.I

08M

S. I

OK

OBM

Fk.Jid #I

Selected Ubrary Fltid Delete Densl'y

I

I

Selected Welbore Fll.Jfd Delete

Rename

PPO

Rename

Density

r

r

Type

Type

Base Type

Base Type

BaseFUd

Base Fluid

Model

Model

Data

Data

.----- -

'"To move lilraries between databases, use Import/Export on the root node of the Well

1-40



Chapter 1: Basics

11. Create a new case by right-clicki ng the Database icon ( e ) in the Well Explorer and selecti ng Instant Case from the ri ght-click menu. Incl ude this case in the C lass company. Create new nam es for the remaining hierarchical levels. The well is subsea, in 328 ft of water, with a well head depth of 300 ft, and defau lt s ite elevation of 100 ft.

To include this case in the Class company, select Class from the Company pulldown list.

Names:

r

CompMy: Class Y-our - Pr-ojec - t N_ame ______

Project:

s.te:

l.... IYour Site Name IYour Wei Name

:J

Wei: Wel>ore: rvo;; w_ el>or _ e_Name _ _ _ _ _ _ __ Oesqi:

Case:

IYour Oesqi Name fvour C_a_se Name _ _ _ _ _ _ _ __

Dlllum elevation above: Mean Sea Level Default Datum Elevation:

P

Offshore Wate¥ Depth (MSL to Mudine)

~ ~

rm-

ft

w~ Depth:

t;;' SUbsea

Training (EDM 2003. 16.1 .12 (06.01 .01 . 121); " Clan

- !}

- 9? Class Project

Notice the case you created is associated with the Class company.

- /( Class Sit e

- i Class Wdl - I.. Oass Welbore (S/ 12, - Y

dass Oeslon 0

0 assCase

- . . Your Project Name - /( Your S"lte Mame - j_ Your Wei Name Your Wellbore Name Your Design Narm

- I.. - 'J

0

Your Case Nan-

12. Double-cl ick the case name in Well Explorer to open the case you created in the previous step, if it is not already opened.



1-41

)

Chapter 1: Basics

13. Open the Case> String Editor. After the import, notice that the

string data is displayed . Click Import. When the warning message displays, click Yes to indicate that you want to overwrite any existing string data. Strnglnibaliz~ ~---------------StJing Name

1Afsem1i1y

rt

Sb1119 (MOl

Sectioo TJ1PO

Sl)edy Length [fl)

ITop to Bottom Meas.xed Depth

lpl

::::J

Import Stnng I

l~t

ID

OD fin)

fin)

Item Desaiption

[g)

Import Assembly String From Library

Assembly Name:

I

Highlight the 10.625" BHA string library entry in the Import Assembly String From Library dialog box. Click Import to import the string from the library.

Cancel Help

Delete

I

'To move Lbaries between databases. use lrrc>0rt/Expo1t on the root node ol the \IIel Explorer

1-42



Chapter 1: Basics

- - - -

Lbary

' ng 1.-.111on S rngN- 1062S'BHA

Smg(MDJ Jt79500

II

Sect.,,,Twe Dnl PIPO HNV)l'W'e9" J• HNYy'W'"ltol D1•Co1«

..

s~

Sgec:fy

IT"" IO Bolk:m

Depth

(It)

171)26 50 60 00 3300

:moo :m.oo 5.00

D1•Co&ai Stobeoi 01• Colai St•bilttoi

:noo

MWD Mud Molor

30 00

Sib

500 31.00 5 00

31) 00

300 150

Bt

.,..Sbno

.,:;

Meaued

l er9h

E>q>Ol1

I

l~t

I

- - --'

J 17026.5 171B3_5 ln195 17419.5 178095 17814 5 17S.U5 178495 17S805 17885.5 179155 17945 5 179485 17SOO O

OD

ID

fnl

Item Oesac>bOn

(11'1)

5000 5000 62Sll 5000 8000

8000

4276 3000 2.250 3000 2500 2500

9.000 9 000 8000 9.000

2.500 2.500 2 500 2500 2500 2500

6000

2 •00

8000 8000

10625

2192 DlfPoe5 ... 1950IJll( G N~J.P 49 70 Heevy 'W'e!/'4 0 .. Poe Giant Pncloco. 5 I\. 49 70 pp/ 90 88 Mechano:al J• Daile)' Mech., 6 1/ 4 n 49 70 HNYy 'W'. Di• Pipe Giant Prideco. 5 .._ 49 70 ppl 154 33 Oil Col.¥ 8 I\. 2112 in. 7 H·90 154 36 lrUQllll Blade Stabil« 10 518'"FG. 8>(21/2 in 154 33 01• Col.¥ 8 in. 2 1/2 n. 7 H·90 154 36 lntegilll Blade St(21 12 n 15276 Nori-MagD1•Co1ot8 ... 2 1 12n.7 H ·~ 154 36 lnteglll Blade St~ 10 5/8" FG. 8 "2 112 in 15436 MWD Tool8 8 x2 1/2n 15436 Bor.t HOUSJnOB.9><2 1/2., 7951 8tSlb 6. 6><2112 n 150 00 81-Untoied 8~. 3><10, S.10. 0 614 rl

14. Open the Case> Fluid Editor . Notice there is no fluid data in the Fluid Editor until after you import the fluid from the library. You must click Activate if you want to use the flu id in the analysis. ~

IP Fluid Editor

Click Library.

My

Activate

FkJid #1

11\Jd Density

le.so

RheolooY Model RheolooY Data

!~Plastic IPV and VP

Temperature

170.00

Of

Plastlc Viscosity

124.00

cp

Yield Point

j 12.000

lbf/IOOft >

Fluid Plot

PPO

..:J

3

Fann Data

save RPMs as Defaut: Speed (rpm)

I

Dial

rJ

1

2 3

SM:or Rae (line)

OK

WELLPLAN TM Software Release 5000.1.10 Training Manual


1-43

) Chapter 1: Basics

-

-

f8)

'P Import I Export Fluids

Highlight the 15.1 ppg OBM _~_.,lni b;yymF~IUlds ······ fluid library entry in the ··· •:· Library Fluids column.

Click the right-facing arrow button to copy the fluid from the library to the Wellbore - -1--- 1 - - - - - - - -Fluids list. Click OK.

OK FUd#l

Help

~ ~

Selected Library Fluid

Delete

Density

j

Selected Welbore Fluid

Rename

PPCJ

r

Delete

I~name J

Density

r

Type

Type

Base Type

Base Type

Base Fluid

Base Fluid

Model

Model

.------

Data *To move Lbraries between databases, use lf11)0t't/Export on the root node of the Well

1-44



I

J

Chapter 1: Basics

'P' Fluid [ dilor

-

~ ~ ~ IS.I PPQO&M Fluid # I

Mud Density

ItS.10

RheoloQy Model

Iflin9harn Plastk:

Rheoloc;iy Data T~attxe

-

~

-

PPO

IPV and VP

ro.oo-

·F

Plastic 'mcosll:y

~ cp

Y-teld Point

1,...1-2 .000 - - 1itt100ft>

Fluid Plot

Fam Data

I

Save RPMs as Defd

Shurl

i

ti

Speed (rpm)

O.ll020

)

Dial (")

600 300

1

~

I

2 3

0.0010

(/)

0.0000 0

100

OK

400 200 300 Shear Rate (I/sec)

Uncel

600

000

I.

~

J

15. Using the Well Explorer, right-click the Database icon and select Export from the right-click menu. Specify the file name you want to use and be sure that Save as Type says "Library Transfer Files (* .lib.xml)." Click Save to create the library transfer fi le. You or the person to whom you are giving the file can import the library transfer file by selecting Import from the Database icon's right-click menu.



1-45

Chapter 1: Basics

Configuring the Workspace 16. Continue to use the case you created in Step 11 (using the Instant Case option.)

17. Use View> Tabs. Ip!_Tab Mana;~---- - -

- - - - r1]~

Tabs: Sc nematic

Tab2

Click New to create a new tab. Click Rename to rename an existing tab. Click Delete to delete the highlighted tab.

Delete

Walplot Tabs:

Ale Name Walplot

New j <

> Help

1-46

Delete

1

Rename

J

j



Chapter 1: Basics

Window splitters s-o-

-•a-.._

U>HSOOC.1S<>Q1e.-Ob(W'!SOOO 11.0(090).

- fl Class

o . - IH""O.....,edH'"foSc* · '

- I( CIM$ Sitt - t O.S.w.I

.."'

- ~ ca...-e(l/JOj21!JO)

You can also rename a tab by doubleclicking on it and specifying a new name.

,

- -i

- "0...0..,...

oa...c...

-~-

-

......._

Wd -....

w-.. .......

~

• ._;) RigCOttracb:lts

··lt: D.. r.-.._,,..

· ·~

a) Use View> Schematics> Well Schematic-Full String and then use the Option pull-down list to select Not To Scale. WelSchema!_ac·FulStr Schemallc Options

--~

----~-

-

I

Option Not To Scale

Schernat_l_~_l

~

_ _ _ _ _ _ _ _ _ _ _l.!J



1-47

Chapter 1: Basics

b) On the Editors tab, put the Case> Hole Section Editor in one pane and the Case > String Editor in the other pane. !'Joie Section EdotOI

----

Hole Name:

IHole Section

Hoje Section Depth (MD)

117950.0

ft

Section Type

Meaiured Depth (ft)

Length (ft)

Import Hole Section

I

p Additional Columns Shoe Tapered?

M~ured

Depth (ftJ

ID [in)

Drlt

frn)

Effective Hole Diameter [1'1)

Friction F&etOI

Lneai

E~

Capacity (bbl/It)

r

~

<

J_>

Sting Initiafizalion

Library

String Name lr-1-0.-625 --.-. 8-H-A- - - - - - - - - - - - - - - -

Stnng (MD)

117950.0

Section Type DrilPipe He~yWeigt(

Jai Heavy Weigt(

DrilColar

S~y

ft

j ToptoBouom

Length (ft)

Measi.se d Depth

17026.50 GD.CO 33.00 300.00 390.00

17026.5 17086-5 17119.5 17419.5 17809.5

[fl]

OD

(ml 5.000 5.000 6.250 5.000 8.000

:::::J

lmportSt1roo l

4.276 3.(0J

2.250 3.000 2.500

21.92 49. 70 90.88 49.70 154.33

lmpoll A

Weight (pp/)

ID frn)

Export

Item Description DriUPipe 5 in. 19.50 ppf. G. NC5QP
c) Put the Case> Wellpath Editor on the Wellpath tab.

Y5ection Definition

lder6rcalion

Mame:

jWellpath

Options...

OriQfl!:{:

Qe$ciip(ion:

Originf:

'tiell Depth (MOl INC

MD

.)

ft)

0.0

Generate w~h Ac\ual Stations

ft

0.00

AZ

r·

0.00

TYO (fl)

0.0

DLS

r110001 0.00

AbtTOlt Reff Oft 1·11cntJ ('/100ft

0.00

8zimuth:

VSed

0.00

<

1-48



(fl)

0.0

r-r-jCi.Cil N01th (ft)

0.0

Chapter 1: Basics

d) Open the View > Wellpath Plots > Inclination plot on the Plots tab.

LEGEND - - lncirnllion ~10;--~-t--'-+--t----'-~--:--;-;-;--r-.-;-_,......-+........,,.........~

~

£

as 20

0

-0

~ 30+---+....-+--....-..--+----'1--.------r-----+----i

:J CJ)

ro

Q)

~40+----t--~-t---;.-+--:--;---.--t-i-+-~rl-...-,~

50-t-- - - + - - - - + - - - - t - - - - - t - - - - + - - - 1

-40

-20

0

20

40

Inclination (")

Schematic

Editors

Wellpath 'APlots

WELLPLAN ™ Software Release 5000.1 . 10 Training Manual


ffe.l!_ J

1-49

Chapter 1: Basics

18.

a) In Well Explorer, highl ig ht the Class Case in the Class Project. x

Highlight the case by clicking it. Refer to the Associated Data Viewer to determi ne which items are linked to the case.

EDM 5000. 1 Si'lQie User Db (EDM 5000. I.7 .O (09 .OJ.

- fl a ass

Class Project - /( Class ste Class Wei - I,. Class Welbore (8/10/2010) - '¥'Class 0esq.

- i

In this example, the Hole Section and Assembly use the default __ _-i-i:Tiii"V~;,:;:'; 0 @mtm names of Hole Section and Your Project Nam e Assembly . You can rename items in the Associated Data Viewer by highlighting them and then clicking them again. The active fluid is also displayed .

/( You' Site Name _ v ourWeUName

.t -

I- Yourwenbore Name -

1' Your Design Name

(;) RAO Contract0
0

Your Case Nam e

+ +

0~+ TulxW Properties

+ •

Cataloos

• •• t

to 17, 968.0 rt 15. J PPQOBM

1-50

15. l OPPO



Chapter 1: Basics

b) In the Associated Data Viewer (located at the bottom of the Well Explorer), right-cl ick the Hole Section entry and select Copy. x

er EDM 5000. 1 Single User Db (EDM 5000. 1.7 .O(09.03.

-*'- N

- fa Class

ci.,ss Project

To copy a hole section associated with the highlighted case, right-click the hole section in the Associated Data Viewer. Select Copy from the right-click menu .

Cklis S
- i ClbSS WeJI - I.. ci.,ss Wellbore (8/10/20 10)

- '¥' Class Design 0

Class Case

~~~~~-+-~--:~~Y~our~P~ro~j~ectName

- If Your Site Name - i Your Well Name - I.. Your Wellbore Name - 'lJll' Your Design Name

0

Your Case Name

+ ( ) Rig Contract ors

+

D

+

fi} Catafoos

Workspaces + (I~; Tubolar Properties

> Oeta~s

No Rig • • •

Open

15.1

I

7, 968.0 ft

Pl'·~·~:a~·~s~n~·~-~ 10 PP9

c) In Well Explorer, right-click the case you created in Step 11 and select Paste from the right-click menu.

- . , Class Project Class Site Class Well

"'

- N

10 -

- .i

- I..

-*' -

Highlight the case to which you want to copy the hole section. Right-click and select Paste from the right-click menu.

Class Wellbore (5/ 12,

- 'f Class OesicJn C

Class Case

5 20

Your Project Name /( Your Site Name Your WeU Name Your Wellbore Name Your Design Name

- i - I..

-Y

~-;---------.o m

Open

g

ii&.

a. (I)

0 -0 Q)

:; 30 (/) m

Close

< New Attachment ... New lesson ...

Name

X No Rig Associated , ..

Copy

Ctfl+C

[] Hole Section

Paste

Ctrl+V

Rename

F2

Properties...

Alt+Enter

B 10.6zs" BHA Fluld #I

to 17,9so 8.50 ppg



1-51

Chapter 1: Basics

-

---

-

-

--

-

---

--

-

-

-

-- - - -

-

lpl WELLPLAN 5000. 1

'X

This will req.ilre a save of assoeiated open cases. Are you SU'e you want to copy the Hole Section Group to Case: 'You Case Name"?

Click Yes to indicate you want to copy.

d) Class Project

;..

- I( Class Site

- t. OassWell - I..

dass Wellbore (5/ 12,

- 1fr Cla.ss Design

- 9;7 -

C Class Case Your Project Name I( Your Site Name Your Well Name Your Wellbore Name - ~~ Your Design Name

- .t

- I..

+

f}

+?i %{$

Cl 'ffltij

Company

+ ~ Ful Feat\J'e Oil Co. ~

Notice the Associated Data Viewer indicates the hole section depth _ __ has changed .

1-52

<

.. .

Nlll'l'le

X No Riq Associated .. . [ ] Hole Section

1:1

10.62S' BHA Fluid # I

....

'

v

)

Details No Rig

to 17,968.0 ft to 171 950.0 ft 8.SOppg



Chapter 1: Basics

e) Hole Section Edlor Hole Name.

IHole Section

Hole Sechon Depth [MD~

117968.0

Section Type

~

Ci1$inQ

Casing J - Open Hole

.

~ <

Import Hole Section

W° Additional Columns

ft

Meas1.aed Depth (ft)

12534.0 1&131.0 17968.0

I

Shoe Meastsed Tapered? Depth (ft)

Length (ft)

17968.0 16131.0

12534.oo r 3537.oo r 1037.oo r

-

ID

Drift

Effective Hole

fnJ

fnJ

D~ei

12.375 10.682 12.250

12.250 10.625

17.500 14.750 12.250

U25 0.30

(bbl/ft)

,. Ex (

0.1489 0.1108 01458

~

v

> Libtary

Suing Name 110.625" BHA

Section Type

Linear Capac~y

ml

Stmg lnibaization

String (MD): 117950.0

Friction Factor

Si;iecify:

It

Length (ft)

IT op to Bottom _:.J

Measure d Depth (ft)

OD

frn)

ID fill)

lmportSuino

Weight (ppl)

I

Expoit

J

Import

J ,.

Item Des~ v

19. Follow the same procedure as in the previous step. 20. Using the Well Explorer, highlight the hierarchy level in which you are interested, then view the linked data using the Associated Data Viewer. a) Well path, pore pressure, fracture gradient, geothermal gradient, and casing designs are linked to the design level.



1-53

Chapter 1: Basics

)(

•

EOM 5000. 1 SinQle User Db (EDM 5000.1. 7 .O (09.C "

- ft Class - •

Highlight the design in which you are interested. The Associated Data Viewer displays the items that are linked to this design.

Class Project

- N Oassste

- .i OassWel - i,.

-*'- N

Cass Wel:lore (8/10/2010)

- VE®C#f·A

0 Class Case Your Project Name Your Site Name Your Well Name - I,. Your Wellbore Name - 1Jll' Your Design Name 0 Your Case Name

- i

<

+ _;:> RIO Contractors • 0 Workspaces

Name

©welpoth

iif Formations U Pore Pressure ~ft Frat Gradlent £) Geothermal Gr~nt ~ ~ camo Assembles Bl T\bilo Assemblies

v

> Details 209 stations to

17,968.0 ft

0 Formation Tops 47 v~

47 values Bottom Hoje: 279.50 •f

0 CllsinCJ 0 Tubinl}

b) Ri gs, hole section, assembly, and fluids are linked to the case level. c) Fluids are linked to the wellbore level.

1-54



Chapter 1: Basics

2 l. In Well Explorer, right-clic k User Defi ned Workspace and select New from the menu. Name the work pace Class workspace and click OK. Notice the workspace you created is now listed as ·'User Defined Workspace" in the Well Explo rer. x

EOM 5000. 1 SirlQleUserOb(EOM5000.1.7.0 (09.03. Class Class Project

- f)

- ii

- I( Class~e

- i Class Wei - I.. Class Welbore (8/10/2010) - 1tr Class Design

Right-click User Defined Workspace and select New from the right-click menu.

0

Class Case

- *1 Your Prol ect Name - I(

Your Site Name

- i Your Well Name - J.. Your Wellbore Name - 'f Your Design Name 0

- Q w

..

Your Case Name

es

(}) Userr"'ml " =J~ + Ill MoO.J ... • ~ Systo Export... B~ TlbA.Y Pr~

• fil Cataloos

x EOM 5000. I ~ User Db (EOM 5000. 1. 7.O (09.03. aass Class Project - I( Class Sito - j Oass Well Class Welbore (8/10/201 0)

- f)

- llP

- J..

- "

-*'

Notice the workspace you created is now listed as "User Defined Workspace" in the Well Explorer.

Cla$~ OesiQrt 0 Class Case

Your Project Nome Your Site Name Yoor Well Name Yoor W ellbore Name - , , Your Oeslon Name Yoor Case Name • _) Rig Contractors Worl
- I(

- .l

- J..

0

- CJ

Dt.

• ii Cataloos <

22. Save and close the case by using the File menu, or by right-cl icking the case name in the Well Explorer.



1-55

Chapter 1: Basics

23. Re-open the case by double-clicking on it in the Well Explorer. Notice that the tabs are those you created. When you save a case, the current tab configuration is saved with the case data. Therefore, when you re-open the case, the tab configuration is automatically displayed. 24. Right-click User Defined Workspaces and select Export. 25. System Workspaces are installed with the software and cannot be changed. You could use a System Workspace as the basis for a User Defined Workspace, but you must always save your workspaces as User Defined Workspaces. Review the tab configurations associated with each system workspace by double-clicking the workspace name in the Well Explorer, or by highlighting the workspace and selecting Apply from the right-click menu.

• D Rig Contractors

A

- CJ Workspaces + (}) User

Defined Workspaces

• (i} Module Workspaces - ~ System Workspaces (JI Bottom Hole Assembly Analysis

(JI Cementiig Analysis (JI Critical Speed Analysis (JI Hydraulics Analysis (JI Real Time Analysis

Apply the workspace by highlighting it and selecting AP-from the right-click menu .

1---

(JJ stuck Pipe AnalystS (JI Su'ge s-b ReQ>. Analysis

C!l a;z '3k&·i!@# M®W

(JI Wei Coruol Analys.!I ~ ~~~

<

26. a) Activate the Torque Drag Analysis module by using Modules> Torque Drag > Normal.

1-56



Chapter 1: Basics

b) Apply the Torque Drag Analysis System Workspace by doubleclicking it in the Well Explorer. Ig nore any error messages displayed in the Status Message area. These errors occur because you have not entered required analysis data. Wei Schematic · Ful S!!!Jg _ Schematic Oplions

_ _ __ _ _ __

_

_

__

_ __

_

-

I

Option Not T0 Scale

Mean Sea Level (100.0 ft)

12534.0 ft 1613 1.0 ft

Mudline (428.0 ft)

13 5/8 In, 88.2 ppf, Q·l25,, 12534.0 ft 11.75 in, 65 ppf, Class Grade, , 16131.0 ft OH 12.250 in, 17968.0 ft

Notice the tabs have changed.

l 17968.0 ft 17968.0 ft •

• \ W ork

i< w ellpath I\ Hole_String I\ Schematic /(BHA )(L I • I

c) x

EDM 5000. ! Single User Db (EDM 5000. 1. 7.0 (09.03.05.228))

- f}

Class Class Project - I( Class Site Class WeD Class Wellbote (8/ 10/ 2010)

- *1

- 1.

- I.. -

Right-click the Module Workspaces node in the Well Explorer tree and select Save As Default.

- tl1 -

'~''

Class Design Class Case Your Project Name I( Your Site Name - j: Your Well Name Your WeUbore Name ~r Your Design Name Your Case Name

0

- I..

-

0

• (.) RIQ Contractors

- Cl Workspaces • (lJ User Oef111ed Workspaces + ~ r.wwwmu ·~5)

~

~ 0~; Tubular Propetties

•8

Catalogs



1-57

Chapter 1: Basics

" EOM 5000. t Single User Db (EDM 5000. 1.7 .O (09.03.05.228))

- fa Class Notice that Torque Drag now displays beneath the Module Workspace node. This indicates that a workspace default has been associated to the Torque Drag Analysis modu le. (This is not the name of the workspace, but rather the name of the module.) You can only have one default for each analysis module, although you can change the default whenever you want.

Class Project Class Site dass Well - I., Class Wellbore (8/ 10/ 2010) Class Design 0 Clan Case 'lour Project Name /i( 'lour Site Name - j: 'lour Well Name Your Wellbore Name 'lour Design Name 0 'lour Case Nam e

- /i(

- .i

- 'J

-

- I.. - 'If

+ [ ) RtQ Contractors

- CJ Workspaces + (}) User Defined Workspaces

- t - -+ -

(})l§§!@'[tj#1.f.!4J

+

GD System Workspaces

(!I Torque Drag +

lit;

+

f j Catalogs

Tubular Properties

d) Using the Well Explorer, right-click the Class Case case in the Class Project project to open the case, if it is not already open. If it is open , you can use the Window menu to switch to this case. e) Click the ~ toolbar icon to activate the Torque Drag module. The tab configuration is the one you specified to use as the default for all Torque Drag Analysis, regardless of which case you are analyzing. f) Double-click the User Defined Workspace you created to apply that workspace. Notice the tab change.

1-58



Chapter 1: Basics

Configuring and Using Plots 27.

a) _ elp.3lhlncirtatoo

Using the Plot tab, place the cursor (arrow) on the data curve of the Inclination plot. Click the right mouse button, and select Freeze Line ....

_

__ _ _ _ _ _ _ _

I "=.. ~ g

5000

£ a. (I) 0 "O

Hide line

10000

(I) .... Cf)

line Properties •••

(I) (I)

~ 15000

Graph Properties ...

0

10

5

25

20

15

Inclinati on (0 )

Specify the color of the freeze line to be green , the width to 3, and change the name of the curve.

(BJ

'P' Freeze line legend: ) Frozen ll1dil1atiOl1i

Width:

5tyle:

:::J 13 :B

IScM

,___0_1<_

Colour:

Symbol:

···I l_Squar_e--iJ

_.I __:~J

b) Identtuion

'f.)ection Defnbon

flJ~

t!ome

Opboni

Qe$0!~

~el Depth (MD~ 11 7968.0

Using the Wellpath tab, change the inclination near 2500 ft to 50 deg.

Oogonti Ongin f;.

Gene
-:1:J757 32630

1.80 50.00 1.83 1.89 1 95

325.79 32532 327 10 pia.61 32S 18 327.00 32919

24289 24781 25212 2564 1 2616 6 26658

Azm'.h

Re!Toil VSect ·11001 (ft) 000 52 000 76 000 101 114 000 000 126 XIS 000 000 483 0.00 49.7 000 51 1

It

lo.oo N..th

Ea•t

RJ

R)

52

76 101 11 4 126 305 483 497

511

·90 .99 11 6 -12.4 ·13 3

Build " /100! 07 03 -0.0 01

0.0

·24 2

~7

·-:1f> 1 ·360 ·369

.979 01 01 ..,

>

I •I



1-59

Chapter 1: Basics

__ elp~ll_ltifknahon _ _ ____ _ _ _ _ _ _ _ _ __ _ _ _ _ _ __ _

0

Notice the two curves visible on the Inclination plot. The legend indicates the name of each curve.

E. Q)

0 "O 10000

~

:::I (fl

(.'O

Q)

:z 0

10

20

30

Inclination (

40

50

40

50

0 )

c)

Right-click the desired curve. Select Hide Line. £i

a. Q)

0

¥ 10000 ::I (fl

('O

Q)

::z 0

10

20

30

IncIi nation (°)

1-60



_

Chapter 1: Basics

~ -----

- - - - ---

--

-

-

------

--- - - -

When a line is hidden. it disappears from the plot.

LEGEND Frozen Inclination

15000

10

5

0

15

20

25

Inclination(°)

d) Add a background logo to the plot. Right-click anywhere on the plot and select Properties. In the Background tab, select the Bitmap radio button. Add the Halliburton logo to the plot. Your instructor can tell you the location of the fi le.

1p1

(EJ

Properties

I

Scale

Axis

]

General/Grid

j

Markets

labels

Font

I

line Styles

Backgiound

Apply To Graph Area Only P°

(' None

J

(' Color: (: Bitmap:

I

legend

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Chapter 1: Basics

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1-62

WELLPLAN ™ Software Release 5000. 1.10 Training Manual


Chapter 1: Basics

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1-63

Chapter 1: Basics

d) Click the Grid View icon (fifth icon from the left on the Graphics toolbar) to view X/Y coordinate data for the plot. Click the Arrow icon (left-most icon on the Graphics tool bar) to return to the Plot view. To toggle between tabular data and plotted data, you can also select Graph/Grid from the right-click menu.

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1-65

Chapter 1: Basics

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Chapter 1: Basics

e) Using the Markers tab, display data markers every 50 data points.

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Chapter 1: Basics

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ChapterE

Drilling Overview Data The data used in this exercise is not from an actu al well . Although an attempt has been made to use realistic data in the exercise, the intent when creating the data set is to display as much software functionality as possible. Therefore, some data may not be realistic. Please do not let the accuracy of the data overshadow learning software functionality.

Workflow In this section, you will drill o ne hole section in a well. During this analysis, you assume previous hole sections have been drilled, and will focus only on the current section being drilled. The following is a brief, general overview of the workflow and does not include a description of all workflow steps. Initial analysis evaluates the stresses acting on the string when the bit is at TD. Adjustments to the drill pipe are made based on this analysis. Next, the torque and drag is evaluated at depths o ther than TD. After all string adjustments based on torque drag analysis are completed, hydraulics analysis begins. First, hole cleaning is reviewed. Flow rate adjustments are made to improve hole cleaning. Pressure losses, incl uding system, string, and annulus are exami ned. Critical annu lar velocities are determined. Pump horsepower requirements are determined. ECDs are analyzed, and bit nozzle sizes are optimized. A fi nal design check is performed to ensure hole cleaning, pressure losses, and ECDs are acceptable. After the hydraulics analysis is completed, tripping surge and swab transient pressures are investigated.



2 -1

Chapter 2: Drilling

Well control analysis is the next step in the process. The kick type is determined, as well as the expected influx volume. Using the estimated influx volume, the kick tolerance is examined. A kill sheet is generated, and the well control animation is used to display the pressures and other parameters as the kick is circulated out of the wellbore. After well control analysis is completed, critical vibrational speeds are investigated, as well as the stresses, bending moments, and displacements acting on the string. Next, the BHA performance is investigated, including the response of the BHA to various WOB and ROP combinations. Finally, the forces required to set, trip, and reset a jar in the event the pipe becomes stuck are determined.

Workflow Solution Solutions for the workflow steps in this chapter can be found in the "Drilling Solution" chapter.

What Is Covered During this workflow you will:

Input General Well Data • • • • •

Integrate between WELLPLAN™ software modules Define the hole section Define the workstring and the component parameters Define the wellpath and how to apply tortuosity Define wellbore fluids

Torque Drag Analysis •

Understand the torque and drag analysis parameters, including: analytical methods stiff string and soft string models mechanical limitations selecting desired tripping and drilling modes defining friction factors

2-2



Chapter 2: Drilling

• • • • • • •

Analyze torque drag at TD, and at other wellbore depths Examine effecti ve and true tension and when to use each Examine fatigue Determine available overpull Determine the torque acting on the string Investigate the possibility of buckling Investigate ways to resolve torque and drag issues

Hydraulics Analysis • • • • • • • •

Examine hole cleaning at various pump rates Investigate the effect of ROP o n ho le cleaning Determine press ure losses Determine annular velocity Input circu lating system information Investigate required horsepower Check ECDs Optimize hydraulics

Surge Swab Analysis • •

Analyze transient surge/swab pressures and ECDs Generate a trip schedule

Well Control Analysis • • • • • •

Investigate well control Determine predicted kick type Estimate influx volume and kick tolerance Evaluate pressures as a kick is circulated out Predict a safe drilling depth Generate a kill sheet

Critical Speed Analysis • • • •

Determine critical rotational speeds Examine the stresses acting on the workstring at various RO Ps, includi ng the type of stress and where it occurs Examine stri ng displacements Review bending moments



2-3

Chapter 2 : Drilling

Bottomhole Assembly Analysis • • •

Predict BHA build and drop Evaluate BHA contact points along the wellbore Analyze the effect of various WOB and ROP combinations on BHA performance

Stuck Pipe Analysis • • •

2-4

Estimate a stuck point for specified surface conditions, and string stretch Determine loads required to set and trip a jar Determine load required to yield the pipe



Chapter 2: Drilling

Torque Drag Analysis (Using the Torque Drag Analysis Module) The Torque Drag Analysis module predicts the measured weights and torques while tripping in, tripping out, rotating on bottom, rotating off bottom, slide drilling, and backreaming. This information can be used to determine if the well can be drilled or to evaluate conditions while drilling a well. The module can be used for analyzing drillstrings, casing strings, liners, tieback strings, tubing strings, and coiled tubing. The Torque Drag Analysis module includes both soft string and stiff string models. The soft string model is based on Dawson's cable model. In this model, the work stri ng is treated as an extendible cable with zero bending stiffness. Friction is assumed to act in the direction opposing motion. The forces required to buckle the string are determined, and if buckling occurs, the mode of buckling (sinusoidal, transitional, helical, or lockup) is indicated. The stiff string model includes the increased side forces from stiff tubulars in curved hole, as well as the reduced side forces from pipe wall clearance.

Data Import for Exercises At this time, it is necessary to import the training data. Select File > Import > Transfer File from the drop-down menus and import Training Company.edm.xml from the training data folder.

Input and Review Well Configuration and Analysis Options I. Using the Well Explorer, open the Case titled "Drilling." 2. Activate the Torque Drag Analysis module. 3. What is the mudline depth (MSL)? 4. Review the hole section information. a. Why is the riser length 590 ft? b. What friction factors are used?



2-5

Chapter 2: Drilling

5. Review the string information. Note The length of the top row cornponenl is automatically adjusted.

a. What is the string depth? b. Does the d1il l pipe weight include the tool joint weight? c. What type of connections are used for the drill pipe, and what is the make-up torque for the drill pipe connection? 6. Review the wellpath information. a. What is the best azimuth to view the View > Wellpatb Plots > Vertical Section plot? b. How can you use this dialog box to set the Vertical Section plot to use that azimuth? 7. Apply tortuosity to the open hole section. Use the Sine Wave Tortuosity Model, 12,500 ft MD Top, a 500 ft Angle Change Period, a 0.5 degree magnitude, and a 30 ft Depth Interval. Note In this example, only one MD Top is specified. Therefore, the same tortuos ity will be applied co all data points below the specified MD Top.

a. When should you use tortuosity? b. When using the Sine Wave model, why should angle and pitch not be a multiple of each other? c. Review the Inclination and Azimuth plots. What is causing the "corkscrews?" 8. What fluid is used in the analysis? Torque Drag Analysis uses viscosity and density for the analysis.

2-6



Chapter 2: Drilling

9. S pecify the Torque Drag Analysis setup options. Check all the boxes in the Mechanical Limitations section. T hi s information will now be displayed on the applicable plots. The Soft String model is more widely used than the Stiff String model. For more information, re fer to the online help. 10. Review the additional analysis parameters. a. From what source are the friction factors coming? (Calibrated, Hole Section Ed itor, and so on) b. What operations will be analyzed? c. What is the WOB (or overpu ll) and the bit torque?

Analyze Results at TD Using the Normal Analysi s mode, you will review the results when the bit is at TD (total depth). Later, you wi ll use Drag Charts to review the results when the bit is at other depths along the well path. 11. Review the Summary Loads table. a. What problems exist? b. Can you dete nnine where the problems occur? c. What is the overpull margin with and without tortuosity applied? Continue the exercise with tortuosity applied. d. If you consider viscous drag effects of the fluid acting on the drillstring, what is the overpull margin? What additional problem have you introduced and in what mode of operation? Do not consider viscous effects after thi s point. e. Does buckling occur? 12. Review the Effective Tension plot. a. Why not use the True Tension plot? b. Which operation is close to exceedi ng the tension limit? c. Is buckling predicted based on this pl ot?



2 -7

Chapter 2: Drilling

13. Review the Torque Graph to determine the location in the string when the torque limit is exceeded for each operation indicated in the Summary Loads table. 14. Review the Fatigue plot to determine where fatigue may be a problem. a. What is fatigue, and why is it important?

I

Hint

Refco· to the ooHote help

b. What is one possible cause of the fatigue? 15. Review the load data to determine which limi ts are exceeded during the Backreaming, Rotating On Bottom, and Rotating Off Bottom operations. When backreaming, at what depth is the yield strength and utilization factor exceeded? 16. What can you do to avoid the problems in the string? There are several possible options. For this exercise, change the drill pipe. a. One option would be to change the drill pipe to 5", 25.6#, S, FH, Class l pipe. b. Review the make-up torque and fatigue limits for this pipe. I 7. Review the Normal Analysis Summary Loads table as another means to confirm the problems are resolved. Is the overpull over-designed? 18. How could you save some money on the string? Continue to use the S grade pipe in the top 7,500 ft of drill pipe. Because the original drillpipe (5", 19.5 lb/ft, G, NC50, P) was sufficient below that depth, change to the original pipe below 7,500 ft. Review results again using the Summary Loads table. (7,500 ft of S pipe is used because the problems began about 7 ,000 ft. The additional 500 ft allows for a margin of safety.) There are other possible drill pipe configurations that would be acceptable. Because of time constraints, additional analysis will not be performed in the course setting at this time.

2-8



'

Chapter 2: Drilling

We have analyzed results when the bit is at TD (total depth). Now we will use Drag Charts to review the results when the bit is at other depths along the wellpath.

Analyze Torque and Drag at Other Depths 19. Select the Drag Charts analysis mode. 20. Analyze every l 00 ft from 0 to TD. Note Much of the information on this dialog box defaults from the data specifi ed in the Normal A nalysis mode.

2 1. Review the Hook Load chart. a. What does the Max Weight Yield line represent? b. How can you determine the overpull at a specific point? 22. Review the Torque Point chart. a. This plot displays the torque at what depth? b. Why is there 0 torque while tripping in and tripping out? 23. Specify an RPM of 80 for the tripping operations (as with a top drive). Notice the difference in the plot. Set the RPM back to zero before proceeding. 24. Review the Minimum WOB chart. Look at the last data point and compare the results to the Normal Analysis Summary table res ults. Notice the Run Depth is the same as the bit depth.



2-9

Chapter 2: Drilling

Analyze Hydraulics {Using the Hydraulics Module) The WELLPLAN H ydraulics module is designed to assist the engineer with the complicated issue of designing hydraulics. The module can be used to optimize bit hydraulics, determine the minimum flow rate for hole cleaning, determine the maximum now rate to avoid turbulent flow, analyze hydraulics for surge and/or swab pressures, and quickly evaluate rig operational hydraulics. The module provides several rheologica l models, including Bingham Plastic, Power Law, Newtonian , and Herschel Bulkley. The chosen rheological model provides the basis for the pressure loss calculations.

Input and Review Well Configuration and Analysis Options 25. Access the Hydraulics modul e. 26. Review the string information. a. What are the bit nozzle sizes? b. What are the flow rates and pressure losses for the mud motor? c. What are the flow rates and pressure losses for the MWD?

Analyze Hole Cleaning 27. Access the Hole Cleaning - Operational analysis mode. 28. Review the analysis parameters. 29. Review the Hole Cleaning Operational plot at 600 gpm and a rate of penetration (ROP) of 50. a. What is the minimum flow rate to clean the wellbore? b. What is the bed height in the riser? c . What is the bed height in the casi ng (between the drill pipe and the casing)?

2-1 0



Chapter 2: Drilling

d. Will changing the flow rate help clean the annulus (not including the riser)? Try 615 gpm. Note

Use the slider on the plot to change the tlowrate

e. How much add itional flow is needed to clean the riser? Try a flow rate of 720 gpm. f.

To pump at the lower flowrate of 615 gpm, add a booster pump. The injection depth is 590 ft, 40° F injection temperature, and an injection rate of I05 gpm.

g. Now that you have added a booster pump, set the flowrate to 615 gpm. Are the wellbore and riser clean? 30. Review the Minimum flow Rate vs. ROP plot. Note

Using this plot, you can perform sensitivity analysis by selecting any RPM . To increase ROP, you can vary the RPM or the flowrate.

a. At 0 RPM, what flowrate is required to achieve an ROP of 70 ft/hr? Rotary speed is the speed of the rotary bushing or the top drive. b. How fast can you drill, and keep the well bore clean, if you rotate at 30 rpm? c. Set the rpm to 25 before proceeding.

Analyze Pressure Loss and Annular Velocity 31. Access the Pressure: Pump Rate Range analysis mode. 32. Review the surface equipment and mud pump information. a.

What is the surface equipment rated working pressure?

b. What is the maximum discharge pressure and horsepower rating of the active pump?



2-11

Chapter 2: Drilling

33. Now that you know you need to pump at 615 gpm to clean the wellbore , analyze pressure losses for a range of fl owrates to determ ine if your pu mps can handle the requi red flow. Use the fo llowi ng analysis parameters: • • • •

Analyze rates between 475 - 725 gpm using an increment of 50 gpm. Include mud te mperature effects. Include tool joint pressure losses. 9 hr circulatio n time

a. W here do the Maximum System Pressure and the Maxi mum Pump Power come from? 34. Review the pressure losses. Are the system pressures losses too high at 615 gpm? 35 . Change from the 5,660 ps i pump to a 7,500 ps i pump. Note To use the active pump in the analysis, you must update the Pumping Constraints on the Parameter > Rates dialog box by clicking O btain from

Circulating System.

36. Is there still a pressure loss problem? 37. Review the Annular Ve loc ity plot. a.

Is there turbulent flow ?

b. What is the minimum flowrate that causes turbulent flow ? c. If you want a turbu lent flow regime in the open and cased hole, how fast would you need to pump? Hint Use the Annular Pump Rate plot.

38. Save your data to the database.

2-12



Chapter 2: Drilling

Determine Required Horsepower 39. Check the required horsepower using the Pressure: Pump Rate Fixed analysis mode. Pump at 6 15 gpm. a. What is the standpipe pressure? Is this less than the maximum pump pressure? b. Using the pie-charts, review the power losses in the drillstring and annulus. What are the total power losses and how do they compare to the available power for the pump you selected? c. Using the pie-charts, review the pressure losses in the drillstring and annulus. What are the total pressure losses? d. Activate the other 7,500 psi pump and use both in the analysis. (Both 7,500 psi pumps should be active.) Hint This is a two-step process: one step to activate the pump, and the other to use the pump in the anal ysis.

When using multiple pumps, the pump pressure used in the analysis is the minimum pump pressure for any active pump. However, if using multiple pumps, the HP used in the analysis is the combined HP of all active pumps. e. Clear the status messages.

Check ECDs 40. Continue using the Pressure: Pump Rate Fixed analysis mode to check the ECDs. a. Using the Circulating Pressure vs. Depth plot, is there like ly to be trouble? b. Does the ECO vs. Depth plot indicate any trouble? c. Hide the pore and fracture pressure curves displayed on the ECO vs. Depth plot.



2-13

Chapter 2: Drilling

d. Using the Freeze Line functionality, freeze the remaining curve on the plot. To identify the curve later, change the color and increase the thickness of the curve. e.

Include cuttings loading in the analysis. Note

To include cuttings loading in the analysis, un-check the Mud Temperature Effects check box . You can then check the Include Cuttings Loading check box.

f.

Refer back to the ECD vs. Depth plot and notice the difference in the curves. Why is there a difference?

Bit Optimization 41 . Access the Optimization Planning analysis mode and specify the following analysis parameters. What size nozzles do you need to use to optimize based on Bit Impact Force or HHP? • • • •

The minimum annular velocity is 120 ft/min. Allow three nozzles, with a minimum size of 14/32 nds. Allow I 00% bit flow. Include tool joint pressure losses.

42. Access the Pump Rate Fixed analysis mode. 43 . Use the Rate dialog box to inves tigate the effect on HSI when the

nozzle sizes are changed. a. What is the HSI? b. Change the Local nozzles to three l 5/32nds. What is the TFA? Note

Local nozzles can be used for sensitivity analysis so the String Editor nozzles can be left unchanged. After you finish the sensitivity analysis, you can copy the Local nozzles to the String Editor nozzles.

c. Indicate that you do not want to use the String nozzles. What is the HSI now?

2·14



Chapter 2: Drilling

d. Notice the stand pipe pressure is close to the maximum pump pressure, so use three I 6/32nd nozzles instead. What is the HSI now? e. Copy these nozzles to the String Editor. Note Notice the Item Description field associated with the bit on the String Editor did not change when the Local Nozzles were copied to the String Editor. This field is for description only. You can change the description if you wish.

Final Design Check 44. Review the hole cleaning. Is everything OK? 45. Review the pressure losses. ls everything OK? 46. Review the ECDs. Is everything OK?



2-15

Chapter 2: Drilling

Analyze Surge/Swab Pressures and ECDs (Using the Surge Module) The Surge module is a transient pressure model to determine surge and swab pressures throughout the wellbore caused by pipe movement. This analysis is used for well planning operations when surge pressures need to be controlled and to evaluate well problems related to pressure surges. It is also useful for critical well designs when other surge pressure calculation methods are not sufficiently accurate. The Surge module is based on a fully dynamic analysis of fluid flow and pipe motion. This analysis solves the full balance of mass and balance of momentum for pipe flow and annulus flow. Surge solutions consider the compressibi li ty of the flu ids, the elasticity of the system, and the dynamic motions of pipes and fluids. Also considered are surge pressures related to fluid column length below the moving pipe, compressibility of the formation, and axial elasticity of the moving string. In-hole fluid properties are adjusted to reflect the effects of pressure and temperature.

Input and Review Well Configuration and Analysis Options 47. Access the Surge module. 48. Review the pore pressures. At what measured depth is there a 0.5 ppg pore pressure increase in the open hole section (other than

at the shoe)? (Hint: Use Convert Depth/EMW.)

I

Hint

Use Convert Depth/EMW.

2 -16



Chapter 2: Drilling

Analyze Transient Responses Tripping Out Operation 49. Specify operations data. Specify the following analysis parameters. Use defaults for other options. • • •

Swab analysis. Enter 15,000 ft for the Additional Depth of Interest. Specify 12,500 ft (shoe), 15,000 ft (depth of interest), and 20,000 ft (TD) pipe depths. Use 270 ft/min for the pipe speed at all depths.

For each depth of interest, the analysis will be performed assuming the pipe is at the depths specified in the Pipe Depth column, using the trip speed specified in the Pipe Speed column. 50. Review the Swab Transient Response Plot. Examine all depths, but the follow ing questions pertain to TD. a. Is there a problem? b. How much of a swab effect exists (in psi)? 51. Run a trip schedule for the open hole. What is the recommended safe trip speed? 52. Adjust the trip speed to 150 ft/min, and review the transient plots to confirm the problem is resolved.

Tripping In Operation 53. Change the operation from swab to surge. Leave all other parameters the same as for the swab operation. 54. Review the transient plot. Why was the analysis not performed? 55. Adjust the moving pipe depth, and review the transient response plot at all three moving pipe depths. Are there any problems? 56. Is it possible to experience a "swab" effect while tripping in and a "surge" effect while tripping out?



2-17

Chapter 2: Drilling

Investigate Well Control (Using the Well Control Analysis Module) The Well Control module can be used to: • • • • •

calculate the expected influx volume. assist with casing design in terms of shoe settings depths. calculate expected conditions resulting from an influx. generate kill sheets. determine maximum safe drilling depths and maximum allowable influx volumes .

Well Control Analysis analyzes three different influx types: oil, water, and gas. The default influx type is gas.

If the influx type is gas, the analysis assumes the influx is a single, methane gas bubble. Dispersed gas influxes are not modeled. The influx density is the density of methane at the current temperature and pressure. The compressibility factor, Z, is based on the critical temperature and pressure of methane.

Input and Review Well Configuration and Analysis Options 57. Activate the Well Control Analysis module.

58. Review geothermal data.

59. Review well control setup data. 60. Review the temperature distribution model. 61 . Review the geothermal plot.

Determine Kick Type 62. Specify the Kick Interval Gradient of 0.732 psi/ft. Why is this a kick whi le drilling?.

I Hint Ref" to the onlinc help.

2-18



Chapter 2: Drilling

Estimate Influx Volume 63. What type of kick detection method is used?

64. Review the reservoir info rmation. 65. Review the reaction time. 66. What is the expected in flux volume, and how long did it take to detect the kick?

Analyze Kick Tolerance 67. Access the Kick Tolerance mode. 68. Use the Wait and Weight method. Note Available tabs on the Case> Well Control Setup dialog box vary depending on selected analysis mode.

69. Specify the kick tolerance analysis parameters. • • • •

The Kill Rate is 135 gpm. Specify the shoe depth as the Depth of Interest. Assume a 50 bbl kick. Design for a 14.3 ppg kill mud (0.743 psi/ft).

I Note P
•

Analyze between the shoe and TD. (Depth Interval to Check is 7 ,500 ft). Note The Depth Interval to Check begins at the Depth of Interest.

•

Assume a Gas kick. This is the worst-case kick type. Influx types can be Gas, Oil, or Salt Water.



2 -19

Chapter 2: Drilling

70. Analyze kick tolerance results. a. What is the maximum allowable influx volume? b. Is the annular pressure at the shoe between the pore and fracture pressures as the kick is circulated out? c. What is the highest choke pressure? d. Review the Maximum Pressure plot. How does this plot compare to the Pressure at Depth pl ot? e. Review the Safe Drilling Depth plot. What does this plot tell you? f.

Review the Formation Breakdown Gradient plot. What does this plot tell you?

g. Will there be a proble m if there is a full evacuation to gas?

Use Animation to Review Results 71. Use View> Animation> Schematic to view a representation of the fluids moving through the pipe and annulus using the Wait and Weight method. What fluid is in the well bore and string at the e nd of the animation? 72. View the animation using the Driller's method. What flu id is in the wcllbore and string at the end of the animation? 73. Set the kill method back to Wait and Weight.

Generate a Kill Sheet 74. Access the Kill Sheet analysis mode. 75. S pecify the following analysis parameters: • • •

2-20

Use a choke and kill line (590 ft line length, and both choke and kill line IDs are 3.5 inches). Use the Wait and Weight method. BOP pressure rating is I 0,000 psi.




• • • •

Casing burst pressure rating is L0,035 psi. Casing burst safety factor is 80%. Leak off pressure is 450 psi. Leak off mud weight used fo r the leak off test is 13.8 ppg.

The WELLPLAN software internally calculates the equivalent mud gradient when performing the Well Control analysis. If the calcul ated equivalent mud gradient is less than the fracture gradient, the calculated gradient will be used in the analysis. 76. Optional Step: Use the Notebook module to determine the formation breakdown pressure and equivalent mud gradient based on a leak off test. Use a test pressure of 450 psi. a. What mud density sho uld you use? b. The leak off test was performed at the casing shoe. What is the casing shoe measured depth, and how can you easily determine the true vertical depth at the shoe? c. How can you easily determine the air gap and sea depth ? d. How does the calculated equivalent mud gradient compare to the fracture gradient? 77. Access the Well Control Kill Sheet analysis mode. 78. Review the slow pump information. 79. Review the kill sheet analysis parameters. Specify a 6 bbl pi t gain. Select the pump with the 40 spm s peed.

a. What weighting material is used? b. What shut-in casing pressure is input?

80. Review the Kill Graph.



2-21

Chapter 2: Drilling

81. Does pump efficiency make a difference? a. Freeze the current line on the Kill Graph. b. Change the pump efficiency for pump #1 to 90%. c. Compare the two curves on the Kill Graph. d. Set the pump efficiency back to 95 %. 82. Access the Kill Sheet report. Note The las t page of the report contains an index to assist with locating information in the report.

a.

Review report options.

b. How many sacks of weighting material are required? c. What is the final circulating pressure? d. How many strokes and minutes does it take to fill the drill pipe?

2-22



Chapter 2: Drilling

Determine Critical Rotational Speeds (Using Critical Speed Module) The Critical Speed Analysis module identifies critical rotary speeds and areas of high stress concentration in the drillstring. The analysis uses an engineering analysis technique called Forced Frequency Response (FFR) to solve for resonant rotational speeds (RPMs). The Critical Speed Analysis module is based on a nonlinear finite element sol ution written to include intermittent contact/friction, finite displacement, buoyancy, and other effects that occur while drilling. The Critical Speed Analysis module is designed to analyze the 3D lateral bending vibrational responses of a bottomhole assembly. The analysis can model axial vibrations (vibrations parallel to the drillstring axis), lateral vibrations (perpendicular to the drillstring axis), and torsional (twist) vibrations. The module includes damping and mass effects in order to more accurately represent the downhole environment.

Input Analysis Parameters 83. Access the Critical Speed module. 84. Input the following analysis parameters: • • •

Torque at bit of 2000 ft-lbf Weight on bit of 25 kips Steering tool orientation of 0° Note If you use a steering tool, the orientation will be included in the analysis to determine the original position of the string in the wellbore. Steering tool parameters can be input to the mud motor using the Case> String Editor.

• • • • •

Starting speed of 20 rpm Ending speed of 200 rpm a) Speed increment of 5 rpm b) Excitation Frequency Factor of 3 c) Mesh from 0 to 99999 ft



2-23

) Chapter 2: Drilling

a. Why are you using an excitation frequency of 3?

I

Hint Look io the ooli"e help.

b. Why do you mesh to 99999 ft?

I

Hint Look io the oolioe help.

c. Why is Dynamics disabled? 85. Review the mesh zone parameters. Use the default parameters. a. Why is a mesh used in the analysis? b. In what size elements will the BHA be meshed? c. Why is Aspect Ratio 1 the smallest ratio? d. What is Length 2 used for?

Examine the Stresses Acting on the Workstring This exercise will focus on one critical rpm at 140. In reality, you should analyze all peaks, and the range of rpms near a peak rpm. For example,

for the peak at 140 rpm, you should consider between 130 and 150 rpm. 86. Examine the stresses acting on the workstring. The model used is based on harmonic analysis, therefore stresses are relative and not actual. a. What rotational speeds may result in high relative stress in the string? Look for abnormalities in the curve. b. Where in the stri ng are these stresses likely to occur at 140 rpm? Consider re-scaling the plot to view the data easier. c. What components are at these points in the string?

2-24



Chapter 2: Drilling

d. What type of stress is causing the high equivalent stress? e. Explain the difference between the View > Position Plots > Stress Components plot and the View > Rotational Speed > Stress Components plot. Hint Split the window and display each plot in a vertical pane.

Note Many plots have a "slider" to change analysis parameters.

Examine String Displacements Vibration may result in excessive displacement in all directions. 87. Review string displacements. a. Is there more relative displacement at certain rotational speeds? b. At 140 rpm, how does the relative magnitude component stress in the MWD compare to the relative magnitude displacement in the MWD?

Review Bending Moments and Shear Stresses 88. Review bending moments and shear stress to determine if there are concerns at 140 rpm. Split the screen.

Review Results in 3D Plots 89. Access View> 30 Plots> Resultant Stresses> Equivalent. W hat is the advantage of using a 30 plot to review results? Note Use the left mouse button to zoom, rotate, and move the walls of the 3D plot.



2-25

Chapter 2: Drilling

Predict BHA Build and Drop (Using Bottom Hole Assembly Module) The Bottom Hole Assembly module analyzes a bottomhole assembly (B HA) in a static "in-place" condition or in a "drillahead" mode. Many different fac tors influence the behavior of a bottomhole assembly. These fac tors include more controllable parameters such as WOB, and drillstring component size and placement, as well as less controllable items such as format ion type. Because the performance of a bottomhole assembly is impacted by such a wide and varied range of parameters, predicting the behavior of a bottomhole assembly can be very complex. Engineers in other fields have often relied on the Finite Element Analysis Method to solve complex problems. The Finite Element Analysis (FEA) method solves a complex problem by breaking it into smaller problems. Each of the s maller problems can then be solved much easier. The individual solutions to the smaller problems can be combined to solve the complex problem. Depending o n the number of elements (smaller problems) that the complex structure (overall problem) is comprised of, the solution can become very laborious. Fortunately, the combination of the increasing speed of computing power and creative mathe matics have significantly simplified FEA analysis. Because a bottomhole assembly is composed of many different elements of varying dimensions, it lends itself quite well to the FEA method. The following sections describe the major steps performed by the Bottom Hole Assembly module while solv ing for an "in-place" solution, as well as a "drillahead" prediction.

Input Analysis Parameters and Review Results 90. Activate the Bottom Hole Assembly module. 9 l. Review the mesh zone parameters. Use the default parameters.

2-26



Chapter 2: Drilling

92. Input analysis data and review results. How is the bit tilt relative to the wellbore? • • • •

Torque at bit is 2,000 ft-lbf. Weight on bit is 12 kips. Rotary speed is 120 rpm. Do not check the Enable Drillahead check box.

93. Examine the results for drilling ahead 300 ft. Unless noted otherwise, use the same analysis data as in the previous step.

• •

• • • • •

Check the Enable Drillahead check box . Steering tool orientation is 0 degrees . Drill interval is 300 ft. Record interval is 30 ft. Bit coefficient is 50. a) Formation hardness is 30 . b) Rate of penetration is 30 ft/hr.

a. What is the build rate? b. What is the walk rate?

Determine Where BHA Contacts the Wei/bore 94. Access View > Plot > Displacement. a. Where is the BHA in contact with the wellbore?

b. What does the inclination curve represent? 95. Access View> Plot> Side Force. a. Where are the side forces greater than zero? b. What component has the highest side force?



2-27

Chapter 2: Drilling

Evaluate Effect of WOB and ROP

Note Analysis parameters are shared between modes.

96. Activate the BHA Parametric mode. 97. Specify the following WOB and ROP data. WOB (kip)

ROP (ft/hr)

5

15

25

35

35

50

a. How will the build and walk rates be affected by weight on bit?

2-28




Stuck Point Analysis (Using Stuck Pipe Module) The Stuck Pipe analysis module calculates the forces acting on the drillstring at the stuck point. It can be used to determine the location of the stuck point, the overpull possible without yielding the pipe, the measured weight required to set the jars, and the surface action required to achieve the desired conditions at the back-off point. The Stuck Pipe Module: •

includes the frictional effects of the drill string in a threedimensional wellbore.

•

adjusts for stretch when the string is buckled.

•

uses the WELLPLAN Torque Drag Analysis calculations, including equilibrium equations and stresses, stretch, and buckling calculations.

•

uses yield load limits based on the calculated effective yield stress.

•

does not consider fatigue in the Yield Analysis.

Input General Analysis Parameters 98. Activate the Stuck Pipe module and select the Stuck Point Analysis mode. 99. Input the analysis parameters. • •

Traveling assembly weight is 50 kips. Check all three Mechanical Limitations options and use the values provided.



2-29

Chapter 2: Drilling

Determine the Stuck Point 100.Compute the stuck point. Assume you were tripping out when the string became stuck. The ini tial load of the stretch test was 375 kips, and the final load was 395 kips. The stretch was 23.8 inches. a. What is the measured weight when stuck? b. Where is the stuck point? c. Is the stuck point below the j ar?

Setting and Tripping the Jar 10 I.Activate the Jar Analysis mode. I 02.Specify the follo wing j ar operating fo rces: • • •

Up set and trip forces are I 0 kips. Down trip force is lO kips. Pump open and seal friction forces are 5 kips.

I03.What are the forces to set, trip, and reset the jar?

Yielding the Pipe Yield analysis can be performed to ensure the pipe is suitable for a jar. I 04.Activate the Yield Analysis mode. IOS.Determine if the loads required to set, trip, and reset the jar cause the string to fai l. Is the pipe buckling o r yielding? • • •

2-30

Minimum applied measu red weight is 200 kips Maximum applied measured weight is 500 kips Increment is 10 kips



Chapter 2: Drilling

Backing Off I 06.Activate the Backoff Analysis mode. I 07.Determine the initial surface actions required to backoff at 19,158 ft using the following parameters: • •

Backoff force i 5 kips. Backoff torque is 2,000 ft-lbf.

a.

What is the initial surface action for setup ?

b. Why do you slack off? c. To back off, what do you do?



2-31

Chapter 2: Drilling

2-32



ChapterllJ

Drilling Solution Overview This chapter contains the answers fo r the exerc ises found in the previous Drilling chapter.



3-1

Chapter 3: Drilling Solution

Torque Drag Analysis (Using the Torque Drag Analysis Module) Input and Review Well Configuration and Analysis Options 1. Using the Well Explorer, open the Case ti tled " Drilling."

2. Click the Torque Drag Analysis icon ( ~ ) . 3. The Reference Datum section is located in the Well Explorer. If the Well Explorer is not displayed, click the icon. [f the Reference ) Datum is not displayed, click the Datum button ( at the bottom of the Well Explorer.

l.J!l

Datum: Datum Elevation: Air Gap (MSL):

...J

1 ·· Mean Sea level Mudline Depth (MSL): .• Mudhne TVD:

-

Training Rig:DF 100.0ft 100.00ft

The soo.OOft ~--+- mudline depth is 600 .00ft 500 ft.

4. Use Case > Hole Section.

Hole Name

jHole Secbon

Hole SecCJon Depth (MD~

l21X010

CopySbng

ID fr>I

Length

Section Type

(ft)

Ori! (r>)

Elfeclrve Hole

Frocbon

Qlllfne(e«

Factcw

fr> amg

Open Hole

3-2

1

20'.roO

12500 0

2!lWI 12.375 12.250

12.250

17.500 12250

0.20 020 0.:.1

lneat ~ (bbl/1t)

0.3886 01489 01~58

Excess (X)

RSR Secbon. 20., x 18 ri CAS 13 518 n. 88.2 ppl. Q·125. 0.00OH121/2in



Item Oeicrt)(IOr'I


a. The riser length of 590 ft (490 ft + 100 ft) is based on the Wellhead Depth (490 ft) specified on the Well Properties > Depth Reference tab plus the Elevation ( 100 ft) specified o n the same tab .

I

I

Getwtl Oocith Rel•ence loc.llal .tuc1t Wo

1

o.t\ft ........ ..,.,... -S..L....i

I

-... J o.1....J

-.1a1]

,,.....

co

l

l"9

l

- - 1 °*] "

r

~

...

-

Trtnrooll.IQOf

100 Olt 100 Oft

O .W.EltvotJon

I ~ Gap tMll>

-S..L...i

1-

.......... Oocith (M!ll)•

500 Oft 600 Of\

M);

°"' I

°""~

J __l _~

b. The default friction factors are used. These fric tion factors (0.2 for cased hole and 0.3 for open hole) are generally accepted within the industry as defaults, or a place to begin your analysis. Note lt is a good practice to correlate friction factors to existing data where possible.



3-3


5. Use Case> String Editor information.

a. The bottom of the string is at the String Depth (20,000 ft). Notice that the string is entered from Top to Bottom, therefore the bit is the bottom row of the spreadsheet. b. The drill pipe weight includes the tool joint weight. This information can be foun d in the online help topic titled "String Drill Pipe Data Dialog."

3-4




c. To determine the type of connections used for the drill pipe, and the make-up torque for the drill pipe connection, double-click a non-editable cell in the spreadsheet row that describes the drill pipe. The String Drill Pipe Data dialog box will display. The pipe is 5", 19.5 lb/ft (the stated weight of 21.92 lb/ft includes the tool joints), G grade, P class pipe with a makeup torque of 21,914 ft-lbf. The connections are NC50(XH). !pf

Strin~

ori1IPlpeOat~-. - - - -

(1][8)

From Catalog. •. Geneial

Descr~ IDril Pipe 5 in, 19.50 ppl, G. NC~). P

~

Maniactae1

3

fDril Pipe

Li'leal Capacty

10.0173

Closed End Dispjacement j0.0253

Model No.

I Makeup Torque

Length

flsa>a.oo

rt

Body OD

ls.ooo

11'1

Minimum Yreld Strength

Body ID

14.276

in

Colapse Resistance

1:1.92

pp(

LAppioxrnate \11eight Grade

I

T_ype

NC~)

Comection

~

?J '

Jcs_AP! '!/:) 17

Material

bbl/ft bbl/ft

121914.0 l1osooo.o

It-bl

psi

Porsson's Ratio

13000000100 10.300

Dend y

1490

Young's ModWs

psi psi

lbmlft'

Coelf. of Thelma! Exp.

E·CJSrF

Dril Pipe

..:J

Service Class

IP

Connection OD

1&094

Cornection ID

ll250

Conn. TOlsional Yield

136523.0

ft-I>/

Ultimate Tensile Strenoth

jl.42 lso.oo 120000.0 1115000.0

Average Joint Length

j30.0

rt

Ninlber of Joints

ls~

Tool Joint Length 11'1

'Wlll Thiekness (%)

in

Fatigue Endurance Limit

OK



Caocet_j

Apply

ft % psi

psi

H~

3 -5


6. Use Case > Wellpath > Editor. ~hEdlf0<

\ISect
Ide<1tt IC4too

iw~

!fame:

Optoons

u~

I ~e1oep1h(MDI lio:mo

ft

I

,..... Ge<1e1ate wilh Actwl Stotions

MO

OlS

·nOOI

If!

0.0 600.0 5200.0 5315.0 5413.4 5511.B 5610.2 5708.7 5807.1 5005.5 6003.9 61024 6200.8 6299.2 63976 6496.1 6594.5 6692.9 6791.3 6889.8

6988.2 7086.6 7200.0 72.25.8 12500.0 13750.0 18000.0 18877 9 18976.4 1!Kl74.8 200JD.O

0.00 0.00 0.53 3.53 6.53 9.53 12.53 15.53 18.53 21.53 2453 2753 3!.53 33.53 36.53

39,53 42.53 45.53 48.53 51.53 54.53 57.53 60.00 60.00 60.00 60.00 60.00 60.00 60.00 60.00 60 00 1

0.00 224.84 224.84 224 84 :m.04 224.84 224.84 224 84 224.84 224.84 224.84 224 84 224.84 224.84 224.84 224.84 224.84 224 84 224.84 224.84 224 84 224.84 224.84 224 84 224.84 224.84 224.84 224.84 224.84 224 84

,,z.m1

0.0 6000 51999 5314.B 54129 551113 ~.9

5702 4 57965 5888.9 5979.5 6068.0 6154.0 6237.4 6318.0 6395.5 64698 654Q.5

66076 6670 8 6730.0 6785.0 68-43.8 6856 7 9493.8 10118.8 12243.8 12682.7 12732.0 12781 .2 13243.8

Ongrn.E.

loo jo.o

~

jo.oo

OriginN

000 0.00 0.01 2.61 3.05 3 05 3 05 3 05 3 05 3.05 305 305 3.05 3 05 3.05 3.05 3.05 3.re 3.(li 3.05 305 305 2 18 0 00 0.00 0.00 0.00 0 00 000 0.00 0.00

AbsT0
·nini) 000 0 00 0 01 0.07 0 12 0.17 0.22 0.27 032 0.36 041 045 049 0.53 0.57 0.61 0 64 0.68 0.71 075 078 0.81 0.83 0.83 0 48 0.44 0.33 0.32 0 32 0 31 OX!

It II

Rell Oil

('1100\J 0.00 000 0.00 000 0 00 0.00 0.00 0.00 000 000 000 000 000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 000 0 00 0.00 0 00 0.00 0.00 0.00 0.00 0.00

VS eel ft}

0.0 00 ·15.1 ·180 ·241 -33.8 4 7.2 -64.1 ·84 5 ·108 4 ·135.7 ·166 4 ·200.2 ·237.2 ·2n 3 ·320 3 ·366 1 41 4.6 ·465 6 -519.2 .574 9 -632.8 -701 .5

·717.4 ·3956.1 -4n:J.7 -7333.6 -7872.7 ·7m2 -7993.6 ·8561.7

N0
East

ft}

(ft)

00 00 -15 1 -18.0 ·24.1 ·33 8 ·H.2 ·64.1 ·84 5 -108 4 ·135 7 ·166 4 -200 2 ·2372 ·2773 ·320.3
00 00 -150 .179 ·24 0 ·33 6 -46.9 -63.8 -84 1

-1078 ·1350 ·165 5 -199.1 ·2359 ·275 7 ·318.5 ·3641 -412.3 ·4S3.1 ·516 3 ·571 7 -629 2 -6976 ·713.4 ·39341 4 697.4

Bi.id ·110011 0.00 000 001 2 61 3.05 305 3.05 305 3.05 305 305 305 3D5 3.05

-1m1 ·7828.8 ·78890 -7949 1 -8514.1

3.05

3.00 3.05 3.05 3 05 3 05 3.05 305 218 0.00 0.00 000 0.00 0.00 0.00 0.00 0.00

Wl/lt. ·110011 0.00 0.00 000 0.00 0.00 QOO

0.00 0.00 0 00 0.00 000 0.00 0.00 0.00 0.00 0.00 0 00 0.00 0 00 000 0.00 000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

a. The current vertical section azimuth is 0.0 degrees. It is best to view the View > Wellpath Plots > Vertical Section using the same azimuth as the last survey point. In this example, the azi muth at the last survey po.i nt is 224.84 degrees. View the Vertical Section plot with the azi muth at the original 0.0 degrees, and again at 224.84 degrees.

3 -6




b. Use the Azimuth field in the VSection Defi nition group box to set the viewing azimuth.

LE OEND -

Vertical section plot with vertical section azimuth set to 0.0 degrees.

Vtncll Sec:lion

5000

g 0

>

I-

10000

·8000

-7000

-6000

-5000

·4000

·3000

-2000

·1000

0

Verncal Secnon (ti)

LEOE NO -

Vertical section plot with vertical section azimuth set to 224.84 degrees.

Ve.1Qll Soc:tion

g ~ I-

5000

10000

0

2000

4000

5000

SOOD

Vertical Secnon (ft)



---

10000

12000

3.7


7. Use Case> Wellpath >Options, or click Options on the Wellpath Editor to specify tortuosity. 1 1 /'

Wellpath Options

CT)r8J

a. Apply tortuosity to the open hole sections of planned wellpaths to simulate the variations found in actual wellpaths. Applying tortuosity allows for more realistic predictions of torque and drag for planned wells. See the online help for more information. CAUTION

Do not apply tortuosity to actual survey data.

b. When using the Sine Wave model, angle and pitch should not be multiples of each other because the result will go to zero. Refer to the online help for an example.

3-8




c. Review the View > Wellpath Plots > Inclination and View > Wellpath Plots > Azimuth plots. The "corkscrews" are caused by applying tortuosity. Tortuosity creates "ripples" in the planned wellpath .

-

...,~,nc~

------ ---- -----

- -

-- - -- - -- -- - -----

LEOE N O

-

-

lnClonSJon

rdneCJon w/Tonuos•y

2000 4000 6000

g 8000 £ a. (I) 0 10000 u

(I)

:5 Ill (I) Q)

12000

::e

14000 16000 18000 20000 0

5

10

15

20

25

30

35

Inclination(•)



40

50

55

60

3-9


LEGENO -

Azinuth Azlmih wrrortuosity

2000 4000 6000

g

BODO

li (J)

0

10000

u

(J)

';;:)

"' (I) (J)

12000

:E 14000 16000

1BOOO 20000 0

3- 10

20

40

60

80

100

120

Azimuth (•)

140

160

180

200



220


8. Use the Case> Fluid Editor. The 13.8 OBM is used. To activate a fluid , highlight the fluid name and then click Activate.

::::J

IF«V'IData Temperat\J'e

Plastlc 'llscosty

YieldPorit

~ 20.00

"F Cl>

~ lif/loctt>

FUdPlot

Speed (rpm) -t---t-_,.-.~~-+-"~o-t-

100

400

eoo

aoo

;

1 2 3

600

:m

Dial

n

48.00 28 00

1000

Shtar fb< t (1/HO)

()I(

Cancel

Note The teardrop next to the fl uid name indicates it is the active fluid.



3-11


9. Specify the Torque Drag Analysis setup options using Case> Torque Drag Setup. The Soft String model will be used because the Use Stiff String Model check box is not checked. 1p1

ITJ(g)

Torque Drag Setup Data Hool<.-load/Weight~rdcatOI

Correction

jso.o

l raveing Anembjy Weqc

r

kip

f.nable Sheave Froction Correction

l.tleS Strung Mec::hri:al Elficiere)' (•ingle sheave) Analytjcal Methods

v

Use !!ending Streu Mairkatron

r

Ute St/I String Moder

I' E>
r

Ute '{m:our Torque and Drag

131.0

tonlact F01ce Normaizallon Length Mechanical Lrnitations

P

Block Rating (H01$1rlg S~em)

1750.0

kip

Q

TOIQUll Rating (Rot.mg ecµpment)

1500XJ.O

ft·lbl

P' M~ Weq-,t-on-Bt Rotatrig (no snJsoidal bucking) Q

M~ Weq-,t-on-811 Rolamg (no neic.!I buckling)

!;I'

M~Qverpo..tUmgXofYoekt

I_

OK

1so.oo

,.

Cancel

I0. Use the Mode Data (Parameter> Mode Data) dialog box to review additional analysis parameters. 1 1

1'

@~

Mode Data · Normal Analysis Drling

WOB/Overwl

T01oueat Bit

p Rotaling Do Bottom j25.0

kip

125.o jis.o

kip

120010

ft·lbl

kip

j1500 0

fl·lil

~ ~lide

Oriing

l;l l!bekreami>g

12000.0

ft-Ill

? Rotaling O!f Bottom Tripping

RPM

Soeed ~ TrC>ping!n

11000

IVmin

,v T'illll"l9 .Qut

J180.0

It/min

io-- ,pm rpm lo

Friciiori Factofs r. Hole Section EdtOI

t" Advanced

OK

I

C
_J

Apply_ J _ _He.,

a. Friction factors specified on the Case > Hole Section Editor will be used because the Hole Section Editor radio button is selected.

3-12




b. All drilling and tripping operations will be analyzed because the check box associated with each operation is checked. c. There is either 25 kips WOB while rotating on bottom or sliding, 15 kips overpull for backreaming, and 1,500 or 2,000 ft-lbf torque (depending on the operation). WOB and torque vary depending on the operating mode.

Analyze Results at TD I l . Access the View > Table > Summary Loads table. The Measured Weight indicated in this table is the hookload .

\olOB to Hel Buclclo IROla«r>gJ

je1 5

ke>

d. 1187382

ft

\I/OB to Sn Buckle IAOl«ngl j11 0

kC>

IJ

j187J82

tt

ovor"" M.,ll"'IT'W""}Outl

j1 s

kC>

:tclYiekt j90oo

:t

Plclc.UpWeoolll

pno

kci

Sloc:k.Off JlllO

kC>

Lood!Aso 8ACKREAMING T AtF'f'l ~lG o u r ROTATING ON BOTTOM TAIPPl ~IG IN ROTATING Of'FBOTlOM I

3324

270

190680

9320

«O. • 3' 0 19068 0 932.0 ~· 223 1$269 • 3731 l3.U 182 13561 B 6435 2 3174 ?.; 3 17'Jl7 5 209L 5 ~· 3·~~......:.; 1 5~ 5 ~--1.1 10235 ~3"-~~ 97~ 64~ 7~~~~~~~

a. Several problems exist. Refer to the online help for a definition of all fai lure flags. The X fl ag indicates the yield strength and utilization factor is exceeded. In this example, this occurs when backrearning. The T flag indicates the make-up torque is exceeded. In this example, this occurs when backreaming, rotating on bottom, and rotating off bottom. The F flag indicates the fatigue e ndurance limit is exceeded. ln this example, this occurs when backrearning or rotating off bottom. b. Using this table, it is not possible to tell where in the string the problems occur. rn the following steps, you will look at other plots and tables that provide this information.



3-13


c. The overpull margin with tortuosity is 1.6 kips, and without tortuosity is 7.3 kips. Toique Or.;g Load Surnm
W'OB to Hill Buci
kip

l!J•

118738.2

ft

71.0

kip

at· 1107311.2

ft

'W'OB to Sn Buckle (Rotamgi OverpYI Ma1gn (Tr~ Out)

16

Pick·Up W'ef!#

1123.0

kC>

LoadCa$e

kip

STF

BACKREAMING TRIPPING OUT ROTATING ON BOTTOM TRIPPING IN ROTATING OFF BOTTOM SLIDING ASSEMBLY

8

~olYreld ~ Slack-Off ~

TOl(tUe at Rota1y Table

(ft.flf} 29501 8 00 27400.0 00 269819 200!0

XTF -T-

- TF

%

ke>

\Ifrd.op \lllh

'Windup \tlrthot.rt

TOIQl.Je (revs)

TOIQl.Je (revs)

!kill)

241 00 22.8 00 23.6 00

261 00 254

00 236 2.6

MeasuredW

332.4 440.4 292.4 2344 317 4 214 3

Total Stretch (ft)

AmiStren~o

M-uied Depth ft)

lnBO lnB.O 156269 13564.8 17937.5 10235.3

270 34 0 223 1a2 253 155

BIT

rn

4:; ~

2C 97

TorQVe (Ir~ Load Summar

woe to Hill Buckle !Rotamo~

fB0.7

WOB to Sn Buckle (Rotat119}

69.5

kip

al

OverpYI Ma1gn (T llPIJllO Ot.t)

,1.3

kip

%o1 Yreld

P1ek-IJp 'Well#

,117.3

kip

Slbek·Off. 82.7

l.04dCate BACKREAMING TRIPPING OUT ROTATING ON BOTTOM TRIPPING IN ROTATING OFF BOTTOM SLIDING ASS EM BLY

3-14

kip

STF

-TF -T- TF

8t. '1mo

Torque at Rot41y Table B (ft.flf)

2S833 7 00 272135 00

265386 20000

19008.0

f90"00

\Ifrd.op W•h TorQUe (revs)

254 0.0 252 00 231 2.6

ft ft

% kill

W'rd.op \lmioul Torque Mea:suredW (r•m) (kip)

23.5 00 226

00 231 0.0

3324 434 7 292.4 234 7 317 4 214 4

Total Stretch {It)

A>Gaf Streu-0 Measured Depth

27.0 335 22.3 183 25.3 15.5

~ti

1n80 1n8.0 15Eal 1 136232 179111 10243.6

BIT (ft)

4:;

s:: 2C 97



)


d. Check Use Viscous Torque and Drag in the Analytical Methods section of the Torque Drag Setup Data dialog box. ~ Torque Drag Setup Data

ff)[E)

Hook-load/Wetght-lndcatOI C01reclion

jso.o

I raveling Assembly Wet!;#;.

r

.E.nable Sheave Friction Correction

l,ine$ StrLng: ,Mechanical Efficiency (single sheavei

Analytical Methods

P

Use lten
r

Use Sl)lf Suing Model"

P

Use Yiscous T01que and Drag

r Not ava~ for Drag Chatt. Caliblation mode$ and RT Module) 131.0

,Contact Force N01malization length:

It

Mechanteal limitations

j750.0 j50000.0

p Block Rating (Hoistng System)

P TOlque Rating (Rotating equipment)

kip

lt-lbl

P M~>
OK

Cancel

The overpull margin is -2.6 kips, and the yie ld utilization fac tor is exceeded during tripping out

\A/OB to Hel Buckle (Rotatingi

1016

kip

at (18730 2

It

woe to Sin Buckle (Rot~t

ln.o

kip

at: j1873R2

ft

jrooo- - ;:

OverptAI Mar9n (TrWing Out~

1·2.6

kip

~ ol Yield

Pick·Up WeV>t:

1127.2

kip

Slack-Oii: ~-- ke>

Tor~at

LObdt:a>e

STF

BACKREAMING x- TRIPPING OUT ROTATING ON BO -r- TRIPPING IN ROTATING OFFBO - TF SLIDING ASSEMBL --- -

Rotal)I Teble

\Yll"d4> W ith

Torcµo

~19.4

0.0 27917.6 0.0 27499.5 2000.0

264 0.0 257 00 23 9 2.6

'W'll"d4> \,\!'thou(

TorQU$ 24 5

00 231

00 21 9 0.0

Me
'Wtitt;J'I. (kipJ

332.4 4«.6 2S2.4 2313 3174 2.14.3

Mal Strett-o Total s"' Stretch Measured BIT Me. (f\) Depth fl D 27.0 19068.0 9320 34 2 19068.0 9320 22.3 156269 4373.1 18 0 13406.5 65935 25.3 17907.5 20925 15.S 10235.3 9764 7

e. No, buckling is not predicted to occur. Notice the buckling flags (Sor H) are not displayed in the table.

WELLPLAN ™ Software Release 5000. 1. 10 Training Manual


3- 15


12. Access the Torque Drag Effective Tension plot (View> Plot> Effective Tension). QI.le Drag EtleclJve Ten:.on

G1"'Ph

_

_

_

_ _

L EG EN D - T~Lirri

-

-

-

Hdcal!U:ltng(NonRotoling)

Heteal a.clclng (Rotetrog)

·600

· 400

· 200

0

Tension (kip) 200

400

600

800

1000

1200

1400

1600

1800

S-rusri:lftl Buckling (all open1llons) ..._._+'-'......_........_......_.-+-'-......_'-+-'......_....._...._.-'+.._._.._._._......_~_.__._....._.f-'-L-'-'-.._._._._,_......_.._._._._,_..o....u'-+-'-

Baclcreemlng

Side Orlln!I Rotole Off Bottom Rotole On eottom

Tripprog OU Tripping In

g

8000

£ a. (]) 0 10000 -0

~

:::> (fl

('I) (])

12000

::E 14000

16000

18000

20000

a. The True Tension plot should only be used for stress analysis . If you want to determine when the string will buckle or fail due to tension, use the Effective Tension plot. b. Notice that the tripping out operation is nearing the Tension Limit at the surface, resulting in the very low overpull margin . c. All operation curves fall to the right of the buckling curves, therefore buckling is not predicted to occur.

3- 16




13. Access View> Plot> Torque Graph. Notice where the curves cross the Torque Limit line. T he curves for all rotating operations indicate that when the string is at TD the makeup torque is exceeded above 7,000 ft MD. 0

5000

100DO

15000

20000

35000

45000

50000

55000

2000 LEOENO

-

• 000 -

Torquo U..

=.~.,,.

Rotote Off Bollom Tr\:lllOlgo.t Trlll!*>ol'I Slog

6000

g

9000

O>

c::

s

(/)

O>

c:

10000

0

05 (I)

~

12000

Ul

Ci

u ooo 16000

19000

20000

14. Access the View > Plot > Fatigue Graph. Notice the Backreaming and Rotating Off Bottom operations have a Fatigue Ratio greater than 1.0 at about 5,200 ft MD, indicating a fatigue problem. a. The fatigue ratio is the calculated bending and buckling stress divided by the fatigue endurance limit of the pipe. Fatigue analysis is important because it is a primary cause of drilling tubular fa ilure. A fatigue failure is caused by cyclic bending stresses when the pipe is rotated in wellbores with high dog legs.



3-17


5000

10000

Torque lft-lbf) 15000

20000

25000

30000

35000

40000

45000

2000

6000

g

8000

£ a. ~ 10000

~::0 ~

12000

:E 14000

16000

18000

20000

3- 18



50000

55000


b. Use View> Wellpath Plots> Dogleg Severity to review the doglegs. Notice the high doglegs beginning at about 5,200 ft.

l'GEND -

Doglog-ly

-

Dcglev Sewrty w/Tortuoeey

2000

4000

6000

§:

8000

t a.

~

10000

'O Q)

'5

ig

12000

~

14000

16000

18000

20000

0 00

0 20

0.40

0.60

0 80

1.00

I 20

140

I 80

1 80

Dogleg Seventy (•11 OOft)

2 00

2.20

2 40

2 60

2.80

3 00

15. Access View> Table> Load Data. Note The flags in the STF co lumn that indicate what limit is exceeded.



3-19


The problems beg in around 7 ,000 ft MD. While backreaming, the X fl ag in the STF column displays at 0 ft MD, indicating the yield strength and utilizatio n factor is exceed at the s urface. •11~:1,.;L

~1t.,i, • ,E.,.~~'Y•;

Ma Fotce AoNI Foooe

10155 OP

'85828

llJ.C56 DP

4$4640

~-DP

4"'5

£885& Of'

lllll U

4B.!Z55

4822 55

4~37

'12766 411315

47'1631 478ln 416"l68 479; 9) 47, 211 '727 66 Hl315

4&:Ja 41

409841

DP OP C'P OP DP DP 67458 OP 67158 DP

418ln ' Jf.368

' r.69)

'''211

-

....

Oeplh

lltJ

m

Cerro Tioe

Cntanc.e

r..... e.

EPt...... Pl

"'

IPcrt

1304 1

OP 64160 OP '3lll 0 DP 650 DP

135541

4~83

4')').t SJ

154 0 131>140 l:itUO

4W

~788

632f.O OP

umo

i>.:'.lGO DP 6-.;G 1 DP

131'040

U7ll9 ,_.,o

P.Atee

"°"'

"'°'

319

":IIll 9

S57

12, 5

~I

,2, 8

965

1.-; 1 1255 1258 l.!$2 1:165

969

!17) 978 982 986

~~ ~ 1

&50'; 9 OP f,1 4~ 9

3-20

- ·· ,,.,...,,. p,_.. 468) 36

~

"'"""" IPtol

A..i Force

T....i

S11~ch

~evt)

(ti

sro.o.w Bu.;llrog ~ol

00

218h7

1JI

75

41 5

00 00 00 00 00

220352

132 132 131

76 77

41 3 411 '1.0

221158 l.21968

17

W1BJ

Ill

7.8

22360 4

13 ,

18

00

Z244JI

11 4

78

OS

00 00 00

Z.."'526 4

13' 135 135

79 79

41) 4 402 400

~103 ~7

,...,,)

Torque

Oieg (l..ol

,_ ,_,

80

S1'eld>

P•I

•l8 •H

s.-

Hok41 BIO.Ing

~~

:ROI

Budlr>Q

•-01

2191l9

123

102

.009

15'.i '

00 00 00

lZLll6 :?ZC9

12)

'38~

wa

~3 .)QI

22l2 2:.41

00

2llt.~9

00

22578 . 22&31'7 2200': 6 -~

lOJ 10 4 104 105 10' 106 106

1~2

1:Jl.7 1'312

1516 1580

.U 2'.be.

"'°

' 5lll 05 ' '1J'.>le w:T!l'.I

l~llll

1~.ol

00

44679'.I 444<349

45"1'.151

6)305
44'9 ' 9

1290 128& 1291 1296

r..que

01eg

1546 15'58 1563 1$7 1571

4'MC51

....

111

127 3

""'I 0

(l..oJ

1270

ee

00 00

00

1~9

AM Forc.e B"°"IEH T

PAIN

•01

105 106 106 107 10 7

.A.oo!F~e BA..odl~fr"

IPtol

8.vlrog

(llj

129 130 130 131

E••Olnll

lr.t..... Pr.-i1.1e

(~I

s.._.

S•etch

'-I

10, 10 '

478ln 476968

FromB•

r.... 1!8 129

00 00 00

o........

&9256 6895.7 6TIS5 7 68357 QKli 7 6715 7

111-bll

'639 1... 2 1£,15 l{,18 165 I

4009 :J)

Como Tioe

ll.pt

4a.?255 '796 37

(lJ

•oJ

r.._

0.ag tl<>I 00

&9.."'56 ::;p 68957 OP 6865 7 OP

Oe(llh

8-!:: T 16l0 1633

6S556 DP

M...._.od

p Aleo

-A

le ll O ft

ttl>40

1.?4

12 4 ll5 125 126

... tZi

'"

'379 377 37S

....

'373



'65 I


16.

a. Use Case> String Editor to change the dri ll pipe to 5", 25.6#, S, FH, Class I pipe. To edit the drill pipe data, double-click a non-editable cell in the spreadsheet row that describes the drill pipe. The String Drill Pipe Data dialog box will display. Click From Catalog to display the Drill Pipe Specification dialog box. Select the API Drill Pipe catalog from the Type pull-down list.

From~alog

ffi~

IP Drill Pipe Cotdlog M!IA.tacit.et Model No

API Ori Pipe

~alog

Twe

Length

Body OD

Normal

Diametet

Weqt.

ll!i:..C..• .

Body ID

I

..:J

Normal

Grade

Connection

Reset

I

OK

1

C«ieel

I

Clan

"

Appioxlnate W

Grade

Material Connection Ori~

H~

SetVice Dau

ComecoonOD

'7 2:i()

n

Walll hc:kness ~

llOOW

ConnectionlD

lf250

n

Fatigue Encbance Lmt

Conn. Torsional Yield

(7871~70 - -

ft lbl

Ukmale Teoie Sttength

rmxi o Jumi.o

Avetage Joint Length

130.0

ft

Numbet ol Joris

[

OK

I

I

1' -- psi psi

63)

Cl!nCel

I

Apply

H~ j

J

__,

Double-click each of the desired parameters to select the pipe you want to use and click OK.

(1J(RJ

IP Drill Pipe Specificotion

Catalog Type tJl'l:l·

NClllWlal Diameter

-~e;et J

3

IAPI Drill Pipe NomiMI Weq,t

..

Grade

Connection

a.,n

OK !Alcel

- -

I I

He_!_j



3-21


Notice the drill pipe has been changed on the String Editor. I

EdolOI 51Tl'l!l lnibaiz*"1 Stll"l!)Name ~·embl)i

Stll'l!l(MOJ jmno

SectiOn TJIP
--

---

-

---

-

--

Lbao;y Export

ft

SQeClv.

ITop to8onom ::::J Me&t.11ed

Leogth

1n1

Depth

1906800 60.00 3000 270.00

100i80 19128 0 191580 19428 0 19878 0 19883.0 19913 0 19918.0 199<49.0 19954 0 199no 19974.0 19996.0 199990

(~)

45o.OO

5.00 31100 5.00 31 00 500 17.00 300 2200 3.00 1.00

lmpoct Stnng 00

10

fl'I)

fl'I)

5.000 5.000 6.250 5.000 aooo aooo aooo aooo aooo 8000 8000 8.000 8000 8000 12.250

20000.0

lmpoct \;/eqt (pp/)

4000 J,000 2.250

2S 35 49 70 90 88 49 70 15433 154.36 154 33 154.36 152.76 154 36 154.36 154.35 15436 154.35 267.00

3.00)

2.500 2.500 2.500 2.500 2.500 2500 2.500

1000 2.500 2.500

ltemO~""'

Dril Pipe 5 ii. 25 60 ppl. S. 5 112 FH. 1 HWGrant Prideco. 5 ii. 49.70 pp/ M~ J111 Ol!iey Mech.. 6 1/4 in Hea'<)I IN.,qt Oril Pipe Grant Prideco. 51'1. 49.70 ppl Dri1Col!lf8in,21/2ii.7 H·90 Integral Blade Stabiizer 12 1/4" FG. a >C2 112 in DC 8on.21/2 rt 7 H·90 Integral Slode Stabi2er 12 1/4" FG. 8 x2 1121'1 NDC8rn. 2 1/2n. 7H·90 Integral Slade Stabilizei 12 1/ 4" FG. 8 x2 112 in MWD Tocl8 , 8x21/2in CtouOver Sub. aooo in. 154.35 pp/. 4145H MOD. 6 518 REG 8entHouMg8 . 8x21121'1 CtouOver. aOOOin.15435ppl. 4145H MOD, 65/SAEG Tri-Cone B~. 3"18. 0.589 W

Note Double-click a non-editable cell associated with a component to view/edit the parameters defining the component

Double-click a non-editable cell associated with the drill pipe and review the parameters defining the pipe. 1p1

@~

String Drill Pipe Data From Catalog...

General Descriplion !DllllPipe 5 in. 25.60 ppl, S. 5 112 FH. 1

~

Manulactllei

Type

~

IDril Pipe

Lr- Capacity

10.0152

bbl/It

Clo;ed End Displacemert

ft-tbf

psi

l1!m!.OO

ft

Make14> TOfque

j0.0258 jm30.o

Bodv OD

j5.ooo

in

Miniml.ln Yield Strength

j135000.0

BodvlD

)4.000

in

Colapse Resistance

ApprOl!imale Wefgt-i

!29.35

ppl

Young's Modulus

Grade Material

Is lcs_APt son

Comection

j5 1/2 FH

Model No. Length

bbllll

psi

l3roXXro-:00 p$I

...:.!

Poisson's Ratio

f0.300

...:.!

DenSlty

1490 (6.90

E-06/'F

Coetf. o1 Thermal Eicp.

limllt'

Drifl Pipe Service Class

Ii

Connection OD ConnectlonlD

17.250 13.250

Conn. TOlsional Yreld

178717.0

Average Joint length

j30.0

3 in

'Wal Thickness(%)

11.42 (100.00

%

in

Fatigue Entbance Limit

1200000

psi

ft-lbl

Ulinate Tensie Sbength j1450010

ft

Number of J~s

ToolJoint Length

OK

3-22

I-

psi

1636 CMC~j



fl

~

J _~~


b. Review the make-up torque (View> Plot> Torque Graph) and fatigue limits (View > Plot > Fatigue Graph) for this pipe. Notice the problems are resolved.

5000

!0000

15000

20000

Torque (ft-lbf)

25000

30000

35000

40000

45000

50000

55000

2000 LEGEND

- li2'"~ 4000 -

Rolote On Bollom Rolote Off Bollom Tr"""1!10..

=.:,',g 6000

g

8000

O>

c::

~ O> 5 (5

10000

~ 12000

ti!

Q

14000

16000

18000

20000



3-23


I or~ Drag FC!/9Jf' Gr!ph LEOENO

=~om

Rot•e On Bollom

Fatigue Ratio 0.050

0 100 0 150

0 200 0.250

0.300

0 350

0 400 0 450

0.500

0 550

0 600

0 650

0.700

0 750

2000

4000

6000

g

8000

£

a. (J)

0

10000

'O

~

::I UI (I) (J)

12000

:2 14000

16000

18000

20000

17. Access the Normal Analysis Summary Loads table. The problems are resolved in all operation modes. Yes, it is possible the overpull is over-designed. W08 IO H
jllil5

h>

.. 1187382

\NOB IO!r BuO!e (Rol.llrn;I

(ij2

ke>

.. 1187382

ft

Clv•1>.I M•11"[T1'1P"'!l0utl

13513

kc>

ltolYllld

l!J.100

:t

PLI UpWOojtol

11~3'

l.40

S.V-Off j100

LoadC-

STF

; /'#, 200,,

3 -24

ft

lo

\Ard-4)~

M~td

T-.. frevil

"'*"'"

2S9 00 2S 2 0.0 249

;:4 .

~u

o.~

SI

fffj

507 3€.64 2966

391'

2J8

BIT

"'

"

;>!;37

l ~S

lH96 14':r50 4 '70

1i.cm 9

'c;'lf!'

1&.'78 4 102073

)~ .. 1 •

sm·



N....,.. Por.i

M-.red Oeptt.

I

2'.il 31 7 21£ 1' 4

4064

0 l4 S

s.n~

ToloiS-~

14>1

200))0 2WXJO 195882 21ml0

4118

irono

00 00

IB:?r8

1767 2


18. You must first insert another row of drill pipe. Because you want to use the S grade pipe in the top 7,500 ft, insert a row of drill pipe below that pipe. To insert another row, highlight the existing row in the spreadsheet immediately below where you want to insert a row, and then press Insert. A bl ank row will be created. Strng EO!or Strno lnitiMzacron StnngNlll!le Jk.--~ ~~~~~~~~~~~~~~~~~ Slln; IMOt j20XXI 0

Secoon l)1:Je Dril~

ft

Si!CdY

ITop lo Bottom Measured Depth

Len¢> (ft)

ft

19
Heavy Wei!tit Jai Heavy Wei!tit Dril Collar St!lbizei Dnl Collar Stablizei Dnl Collar Stabiizet M'WO

Sub Mud Motor Sub Bit

60.00 30,00 27D.OO 450.00 500 30.00 5.00 31.00 5.00 17.00 3.00 22.00 100 1.00

19068.0 190680 19128 0 19158 0 19428 0 19878.0 198830 19913 0 19918.0 19949.0 199540 19971 0 19974 0 19996.0 19999.0

21XDlO

o::J

_

Import Strrig

00

ID

(n)

fn)

5000

4.000

5.000

3.000 2.250 3.000 2.500 2.500 2.500 2.500 2.500

6.250 5-000 8.000

aooo

8.000 8.000

aooo

8.000

E>
1000 2.500 2.500

8.000 8.000

_ _____ _

Import

2.500 2.500

8.000 8.000

_ ____

Ux«y

12.250

Item Di=riptron 29.35 DrilPipe5ii.25.60pp/. S. 5 1nFH. 1 49.70 90.88 49.70 154 33 154.36 154 33 154.36 152.76 154.36 154.36 154.35 154.36 154.35 267.00

HW Grant Prideco. 5 in. 49.70 pp/ Mechanical Ja< D~ Mecll • 6 1/ 4 ,, Hea")I 'Weight Oril ~Grant Prideco. 5 in. 49. 70 pp/ Oril Color 8 in. 2 112 in. 7 H·90 l~al Blodo Stabilizer 121/4" FG. 8 "2 112 in DC8 ri.2 1/2ri. 7H·90 Integral Blodo Stabilizer 121/4" FG. 8 "2 l n in NOC 8 ri. 2 l n in. 7 H·90 Integral Blodo Stabilizer 12 1/ 4" FG. 8 "2 112 in M\llO root a. s .a 1n .., Croos Ovet Sub. 8.000 in. 154 35 pPI. 41451-1MOO, 6 518 REG Bent HouUio 8 . 8 x2 1/2in Crew Ovet, 8000 ri. 154.35 ppl. 4145H MOD. 6 518 REG Tri-O:lne Bit, '.M 8. 0.589 rl-

Select Drill Pipe from the Section Type pull-down list. The Drill Pipe Specification dialog box will display. Use it to select the desired pipe. Click OK to close the dialog box. 1p1

CT)rg)

Drill Pipe Specific<1tion

~alog.

Type

..

3

IAPI OrilPipe NOllWlal Diameter

Nomnal \iliqt 11:~"!.I

Grede

Reset

.

I

OK Cancel H~



I

Class

Comecbon

I I I

3-25


Because the top row of this spreadsheet is automatically calculated, to specify 7 ,500 ft as the length of the upper section of drill pipe, you must specify the section length in the bottom section of drill pipe as 11,568 ft (19,068 - 7,500 ft). Slung Edlloi

Lbary

Export

n

5111"19.l)_ep(h 121m10

Sll"ClY fToptoBotlom

DrilPipe OliPpe

J"'

H~Y/tK,JY.

Dril Cola! Stabizet Dr• Colar Sti>bilzet Dril Colar Stabilizer MWO Sub Mud Motor Sub

7500.0 1ro68.0 19128.0 19158.0 19428.0 19878.0 19883.0 19913.0 19918.0 13949 0 19954.0

30.00 5.00 31.00 5.00 17.00 100 22.00 3.00 1.00

B~

Import

OD fn 5.000 5.000 5000

(fl]

1156&00 60.00 30.00 270.00 450.00 5.00

H~Y/eight

CopyStmg

Depth

LMgth It 750000

Secilon Type

::::J

ltemDewwon

6.2'50

19974 0 19996..0 19999.0 200Xl.O

29 35 Dril Pipe 5 i1. 25.60 ppl, S, 5112 FH, 1 21 92 Dli Pipe 5 in. 19.50 ppl. G. NC~). P 49.70 H\11 Grant Prideco, 5 in, 49.70 ppl 00.88 MecMnicd J"' Daie)I Mech.. 6 1/4 n 49. 70 H~ Weight Dril Pipe Grant Pndeco, 5 n . 49 70 ppl 154.33 Dril Colar Sil. 2112 i1. 7 H·9l 154.36 Integral Blade St~ 121/4"FG.8><2112in 154.33 DC8tn.21/2n.7H·90 154 36 lnt~al Blade Slabittr 121 / 4" FG. 8 ><2 112 n 152.76 NOC 811. 2112 n. 7 H·90 154.36 lnteoral Blade Slabizef 121 /4" FG. 8 "2 112 11 154.36 MWO Tool8 .8 ><21/2n 154.35 Dou Over S.8.000n. 154.35ppl. 4145H M00. 65/8 154.36 Bert Housing 8 . 8 ><2 1/2 in 154 35 Cross Over. 0 000i1. 154 35 pp/. 4U5H MOD. 6 5/8 RE 267.00 Tri-ConeBl3•18. 0589in'

4.000 4.276 3.00l 2.250

5.000 8.000 8.000 8.000 8.000 8.000 8.000 8000 8.00) 8.000 8.000 12.250

199n o

I

1000

2.500 2.500 2.500 2.500 2.500 2.500 2.500 3.000 2.500 2 500

Note

Some longer components (drill pipe, heavy weight) are not automatically assigned a default length in the catalog.

Use View> Table> Summary Loads and notice the problems are resolved. 'HQ~ 10 Hol 8\ICI<~ IAO!O'.r.gl

1816

woe 10 Sn Bucl.le fRototngi

1110

~

.,. j1e7JBJ

«

1187383

OVOlllUI M~ (T._ 0°'1

1220

"" ~

~ dYoeid joo 00

P>ck.lJpW.,,,;.

j1m

kc>

Sladt-Oft

LD«IC.U.

BACKREAMING TRIF'l'INGOUT ROTATING ON sonoM TRIPPING l'I ROTATl'IG OFF sonoM SLIOl~IG ASSEMBLY

3-26

STF

jB6 3

'.!:

kc>

TOlquoatRoYW•h Wn
,,....,,

20))0

2•

00

M._.ed

"'~ ~I

St.rface N°"'

T~Sttotch

3729 48S5 3329

ms

357 9

25'6

111)

Mea.._.ed OeQ!h

BIT

lfll

2SI

mo

"2000)0

)1 1

9320

2IXXXl 0

20.9 17 3 235 150

.:37JI 6592.7 20925

19588 2

•118

2!Xm0 2!Xm0 1790.3

~7

9763•



no

no


Analyze Torque and Drag at Other Depths 19. Using the Mode pull-down list, select the Drag Charts analysis mode. 20. Using the Parameter> Run Parameters dialog box , analyze every 100 ft from 0 to TD. Notice much of the information on this dialog box defaults from the values specified in the Normal Analysis.

Run Definitions Start MD: End MD: Step Size:

r

jo.o 120000.0 1100.0

ft

rt ft ft

T01que/T ension Point Distance from Bit

Driling WOB/Overoun ~

Rotating On Bottom

P

Slide Drilling

~

BackrMmrng

P

Rotating Off Bottom

j2s.o j25.0 J1s.o

TorQue at Bt kip

ktp kip

j200J.O 12000.0 Ji500.0

ft·bf ft·bf ft·bf

Tripping

Soeed

P P

Tripping In Trjppi-ig Out

1100.0 1100.0

RPM

ft/mn

It/min

lo lo

rpm 1pm

Friction Factors

r.

Hole Section EditOI

( Advanced Friction FactOl's ·Senstivily

r

Enable Sensitivity Plot

OK

WELL PLAN™ Software Release 5000. 1. 1O Training Manual


Cancel

Help_ j

3-27


2 1. Access the View > Plot > Tension Point/Hook Load chart. a. The Max Weight Yi eld line represents the minimum yie ld strength of all com ponents currently in the well at that run de pth . b. To determine the overpull at a specific run depth, subtract the Tripping O ut hook load fro m the Max Weight Yield at the depth in which you are interested. For example, the overpull when the bit is at 2,000 ft is approximately 290 kips (442 - 154). TOlque Orog Hool lo-'l
0

_ _

500

__ _ __ _ _ _ _

1000

1500

_

Hook Load (kip) 2000

2500

3000

3500

0

2000

4000

.... 0

0 0

L EG END Side Drlllha Ratelle 01f6ottOITl Ratelle On 6ottOITl

- - Trlpporig OU Trl!)plnQ In ' I 811Clcrelimg

6000

- o- Mexwei!tt 't'leld (Tr~ OU) -0- ...........

Hel actde(T~ln)

8000

g ~ Q)

0

10000

c

;;;)

a:: 12000

14000

16000

18000

20000

3 -28



4000


22. Review the Torque Point chart. LC19101&J1Cf~~CIOO__

- - - -- -

5000

10000

-

15000

-

Torque at Depth lfl.lbf)

20000

25000

30bOO

35000

-o

Mol<"'IJIJ Torque Rotete Ott Bottom Rotete On Bottom

40000

45000

50000

2000

0

0

4000

- - Tripping OU • TNl)f)ingln

0

Beclueerrwig

6000

8000

g 5

a. Q)

0

10000

c

::>

er

12000

1'000

16000

18000

20000

a. This plot displays the torque at the surface unless the Torque/ Tension Point Distance from Bit check box is checked on the Parameter > Run Parameters. Note

When the Torque/Tension Point Distance from Bit c heck box is checked, you can specify a specific depth where you want to know the torque acting at a particular point in the string.



3-29


b. There is 0 torque for trip in and trip out because the RPM field for both tripping operations is set to 0 on the Parameters> Run Parameters dialog box. 23. Use the Parameters> Run Parameters dialog box to enter the RPM. Notice the difference in the plot. Set the RPM back to zero. orque Drag Torqo~ Pooni Chait

0

__

5000

10000

__

15000

_

__ _

_

Torque at Depth
20000

2sooo

Joboo

35000

40000

•sooo

0

2000

-e- Me11e-up Torq0e

4000

0 Rotete Off Bottom ~ Rotete On Bottom - - Trlpll«lgOut 4 TrlPfll"!lln ~ Backreami'lg

6000

8000

g £ a. Q) 0

10000

c::

;:)

0:: 12000

14000

16000

18000

20000

3-30



soooo


24. Access the View> Plot> Minimum WOB chart. The results reported in the Normal Analysis Summary table assume the bit is at the string depth specified on the Case> String Editor. In this case, the string depth is set to TD (20,000 ft). Use the Data Reader to determine what the buckling weights are at TD. The results will match.

LEG END

-+-v.oe to -- ~

-

v.oBto- -(llol"""O)

IS

Wel~t

20

25

JO

35

on Bit (klpl

•O

•S

56

55

60

6S

70

75

80

85

2000

• 000

sono

g ~

~ 10000

c

::>

CY

1 2000

1•000

19000

18000

20000

h= ,r,~T& -:-:-1r.-~ .b~2=;=:w=.11~~Mo;===-====-==-==-==-==-~~..-..,------------lr-----.----:-' .!.i'~ loQ:llFQ>IOO.Olt --S..~ ...... -10001t. ..- -590.011. -

or

Dr

L~S~

__ _

_

·eGO Oft ~··~a.ote\RD
_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __

woe toHel Buckle IRotatngJ 81 6 woe 10 s~ Buckle (Rotaing) In o

~IP

al 1197383

rt

~IP

al 1197383

tt

Ove.pUI Meigrn (T nppo'lg Out)

2295

kC>

%o1Yreld. j9'.IOO

Pick.Up'Vo/tltl;ft

ilZH

ke>

Slack-Ott

load Case

STF

BAQ(REAMING TRIPPING OUT ROTATING ON BOTTO TRIPPING IN ROTATINGOFF SOTTO --SLIDING ASSEMBLY

--- --

Tcrq.ae al \Vrd.ip \tlih Rotaiy T«>le Tcrque (revs) (tt-tlll 312493 236 00 00 287359 229 00 00 28574 9 21 3 2.( 200)0

_

R

API

;i-

_

:t

1833

krp

Wrd.ip WltW Tcrque 21 8 00

206 00 21 3 00

M,,_.ed

'Volt:llJY.

Total Stietch

(l
3729 4813 3329

2746 3579

2546



(tt)

11 7 175 75 40 101 15

NeUialPon NeUialPonl BIT MD (ftj fltJ 200ll0 00 200Xl0 00 19588 2 '119 200Xl0 00 00 200Xl0 2056 7 179413

3-31


Analyze Hydraulics (Using the Hydraulics Module) Input and Review Well Configuration and Analysis Options 25. Access the Hydraulics module by clicking the

J1,I icon.

26. Review the Case> String Editor information. To view or edit the parameters defining a component, double-click a non-editable field associated with the component. A dialog box will become available for you to edit or review the data associated with the component. a. Double-click a non-editable cell associated with the bit to review the bit nozzle sizes. The nozzles are 3- l 8/32nds.

--- - ---------- ---- ---------t7Jr8J From Catalog... _J

~ Bi~ D;~

Nozzle Sizes

General Bit Type:

ITri·Cone Bit

..:::J

.:J

Manufacturer:

!security DBS

Model:

IXL16

Length:

j1.00

ft

Bit (DriU) Diameter:

j12.250

in

P~ot

Hole Size:

r

in

Pass Thru Diameter:

r

in

Approximate Weight 1267.00

Count 1

Size (32nd'1

J

18

3

2

Total Flow Area

ppf

%Nozzle Area Plugged

l otal Flow Area:

Shank Length:

10.15

ft

Shank OD:

j9.500

In

OK

3-32

l

Cancel

%

10.14s

Apply~J



_

Help


b. Double-click a non-editable cell associated with the mud motor to review the flow rates and pressure losses for the mud motor. --

---

--

--

-

---

--

~~------

-

--

- - ---- ------ ------- -

-------

1p1 String Mud Motor Data

From Catalog...

@(8]

_J

General

I

Description Bent Housing 8 , 8 x2 112 in

Type

iJ

Manufacturer Model No.

IBent Housing

::::J j0.0061

bbl/ft

Closed End Displacement j0.0622

bbl/ft

Linear Capacity

Length

122.00

ft

Makeup Torque

j 57000.0

ft-lbf

Body OD

Js.ooo

in

Minimum Yield Strength

,, , 0000.0

psi

Body ID

J2.500

in

Collapse Resistance

Approximate Weight

Ji 54.36

ppf

Young's Modulus

l30000000.00

Grade

l 4145H MOD

Poisson's Ratio

J0.300

Material

Jcs_API 5Dl7

Density

1490

lbm/fP

Connection

j6518 REG

Coeff. of Thermal Exp.

I

E·061•F

iJ iJ

psi psi

Mud Motor Steering Tool Bend Angle Stee1ing Tool Reference Angle Steering Tool Offset

Kick Pad Length Kick Pad OD Kick Pad Offset

Flow Rate

I0.00 '"'I- - - -

JO.OD ft ... ,0-. 00 - - - ft I0.000 in .... l0-. 00 - - - ft

1. j300.0

Pressure Loss

I

gpm

1110.00

psi

gpm

1160.00

psi

3. 10.0

gpm

Jo.oo

psi

4. 10.0

gpm

10.00

psi

2.

jsoo.o

OK



]

Cancel

I

Help

J

3-33


c. Double-click a non-editable cell associated with the MWD to review the flow rates and pressure losses for the MWD. ~StringMWD

oaia - --- ------- -- -- ---- - -- - -

- - --- - - ---

- ~ IBJ

From Catalog... General Desetiption )MWD Tool 8 . 8 x2112 in

Type

Manuracturer

.::::.I

Model No.

JMWO Tool

Linear Capacity

:::::J 10.oos1

bbVft

Closed End Displacement lo.0622

bbl/ft

Length

)17.00

rt

Makeup Torque

j 51500.0

ft·lbf

Body OD

la.ooo

in

Minimum Yield Strength

1110000.0

psi

Body ID

12500

in

Collapse Resistance

Approximate Weight

1154.36

ppf

Young's Modulus

127700000.00

Grade

j15-15LCMOD (1)

..:.)

Poisson's Ratio

j0.300

Material

l ss_15-15LC

3

Density

1485

Connection

j6518 REG

psi psi

lbm/fP

Coeff. of Thermal Exp.

E-06;+F

MWD Flow Rate

Pressure Loss

1. jsoo.o

gpm

'1 40.00

psi

2. laoo.o

gpm

1185.00

psi

3. 11000.0

gpm

1235.00

psi

4. J1200.o

gpm

J290.00

psi

I

ft

Apply

I ___!:!_elp

Sensor Distance to Bottom Joint

OK

Cancel

I_

_J

Analyze Hole Cleaning 27. Access the Hole Cleaning - Operational analysis mode using the Mode pull-down list.

3-34




28. Use Parameter > Transport Analysis Data. {1]~

'P Transport Analysis Data Input Rate of Penetration:

]~mo

ft/hf

Rotaiy Speed:

lo lsoo.o

rpm

Cuttings Diameter:

jo.2so

1n

Cuttings Density:

12., 45

sg

Bed Porosity:

136.00

%

MD Calculation Interval:

1100.0

ft

Pump Rate:

gpm

Additional Input

r

Returns at Sea Floor

OK

Cancel



Help

3-35


29. Review the View> Plot> Operational plot at 600 gpm and a rate of penetration (ROP) of 50. Use the sliders at the bottom of the view to change the ROP and pump rate, if necessary. Use the Data Reader toolbar icon as you have in the past to determine the coordinate values on a plot. LE OE MD

-

!ledHe0!11

..._....;....;_-,r-"

2000

g g> ~

8000 -

OI

§

10000

Gi Q) v c

~ 12000

6 14000

16000

18000

20000 20

40

lnclinaaon (")

60

400

500

600

M1rnmum Flowrate (gpm)

700

4

8

Volume(%)

8

000

OH

100

10

200

20

Bed Height (in)

a. The minimum flow rate to clean the well bore is 716. 7 gpm. This flow rate is required to clean the riser. About 614 gpm is required to clean inside the casing. b. The bed height in the riser is less than 3 inches. c. The bed height in the casing (between the drill pipe and the casing) is less than one half inch. Note T he casing shoe depth is indicated in the Bed Height plot.

3-36




d. As expected, a flow rate of 615 gpm cleaned the annulus in the cased hole section. However, there are still over 2.5 inches of bed height in the riser. L EO ENO -

l f O END

LEGEND

lnCINl>:ln i:;.;:::=~==-==-.u

-

L,,.........:..;,,,:....=.t-..,-~f':'

BedHoil11 J---.---~-11

2000

cooo 6000

g g>

8000

~ Ol

:s 10000 \ti Q)

u

c:

s

0"'

12000 ~

14000

16000

20000

0

20

40

Inclination (')

&O

400

500

600

700

Minimum Flowrate (gpm)



4

Volume (%)

6

I

I

0.00

0 50

1.00

I

I

1.50

2.00

2 50

Bed Height (1n)

3-37


e. A flow rate of 720 gpm did clean the riser. Because 615 gpm cleaned the cased hole section and 720 gpm cleans the riser, I05 gpm of additional fl ow is required to clean the riser. LEO ENO -

l EOENO

h:llnellon

-~v-..

- - ro1.. voune

2000

4000

6000

g g>

8000

~ 5 ro

0)

10000

(J)

u

c:

s!!l

12000

0

14000

16000

18()00

20000 0

20

40

lnchnauon rJ

60

400

500

tlOO

700

080

Minimum Flowrate (gpm) "'6up R.u.

rno:o-

IP"

"4...,,...,. Flow Role

090

1 00

Volume(%)

-2

f7i67 lP"

.... I

3-38



-0

2

Bed Height (in)


f.

Use Case> Hole Section Editor to add a booster pump. Double-click a non-editable cell in the row of data corresponding to the Riser. You must first check the Booster Pump check box before you can input the booster pump information.

rnrBJ

'P Riser Details Riser Outei Dicrnetei

J22.ooo

ll'l

R1$81 Inner Diameter

J20.ooo

in

P Booster Pump

P

Injection Depth (MD}

ls~.o

ft

Injection Temperalure

j4D.O

'F

Injection Rate

l10s.o

gpm

Riser Depth Calculation Type of Riser

!vertical

_:.! ft

Offset

Flex Angle (L0we1}

10.00

Appio~e Weig-I.

Total Riser length (MD l

ppl

Js~.oo

ft

""Selectng this option ~ overwrite survey stations in the wellpath editor with the ~culated wellpalh points

OK

Help

If Catenary is selected for the Type of Riser, the angle will be used in the analysis. All analysis that considers wellbore deviation will be affected. g. Yes , the wellbore and riser are clean. 30. Access View > Plot > Minimum flow Rate vs. ROP plot.



3-39


a.

If you want to drill with an ROP of 70 fUhr and an rpm of 0 , a flow rate of 635 gpm is required to clean the wellbore.

Hydrat.ks CuU1119~ Tran: port Minimum Flow Rate LEGEND - - S.roJ" DP In 20 .000" RSR - - S.roJ" DP In 12 .375" CAS S.roJ" DP In 12.250" OH

850

-soo E a. 9 Q)

~

750

~

~ 700

LL

c

~ 650 600

0

50

150

100

200

250

300

ROP (ft/hr)

Rotary Speed:

3-40

io- rpm

SettliigVelocity: fls.8

ft/n1n

800$ter FUr4l Rate:~ gpm Yield Point

fa 00)- lbl/100'tl

WELLPLANTM Software Release 5000.1.10 Training Manual 恭贺新禧! http://www.egpet.net ‫ﺷﻛرا ﻟك‬

350


b. About 70 ft/hr. LE OE NO 5 OOOin DP In 20llOOln RSR S.OOOin DP In 12 37Sin CAS SroJln DP n 12250on OH

-

850

800

' [ 750

.9 Cl>

e~ 100

u: <=

::E

650

600

550

500

20

•O

60

80

100

1'20

;-:-:-~ AOla
~
8oootm Pull> Rote

HO

160

180

200

ROP (Mlr)

fi050 IP"

Yield P
220

2•0

260

280

JOO

320

3• 0

~ U/100~

c. Specify the rotary speed in the Rotary Speed field at the bottom of the window.

Analyze Pressure Loss and Annular Velocity 3 1. Access the Pressure: Pump Rate Range in the Mode pulldown list. 32. Review the surface equipment and mud pump information using

Case> Circulating System.



3-41


a. The surface equipment rated working pressure is I 0,000 psi.

~ Circ~lating System

(8J I

Surface Equipment JMud Pumps Mud Pls + E.nviroivnent Surface EqUpment: Rated W0tkin9 Pressae:

j 10000.00

psi

r.

Specfy Pressure Loss

1100.00

psi

r

Calculate Pressure Loss

SUrface Equipment Type:

jIADC

Surface Equipment Data

(" (" (

..

Cancel

3-42

J

Apply



Help

j


b. The maximum discharge pressure is 5,660 psi, and the horsepower rating is 2,000.

I

Surface Equipment Mud Punps Mud Pits + Environment

Active

J- 1= ..L rP' ~ J-

Pl.rnP

Name

Pl GARD P2GAAD P3GARD

Maxinum H01sepo¥ Vclumetnc Maximum VoVStk Maximum el Speed Dischar~ Efficiency

(gal/slk)

3.394 3.394 4.740

(spm)

PTessure

(psi)

Aati-.g (hp)

115.00 7500.00 200l.OO 115.00 7500.00 2{0000 115.00 5660.00 200),00

P1.rnP Rate (gpm)

(%)

95.00 95.00 95.00

I

Add from Catalog

I

I

370.8 370.8 5178

J.

_ _o_K__

Cancel

J

Apply

J.

Help

Note The Active check box is checked to activate the pump. Only the active pump will be used in the anal ysis.



3-43


33. Use Parameter> Rates to specify the analysis parameters. IJ;I

Rat~s ----

-

-

-------------------------------@ rrg) Purnpl'lg Coostrairts

Pump Rates MirwTun Pump Rate.

1475.0

gpm

Max:nun Surface Pres;ue

15660.00

psi

lnaement Pump Rate·

150.0

gpm

Max1TUT1 Pump Powei.

lm:i.oo

hp

Maximum Pump Rate.

1725.0

gpm

MaxmrnAlowable Pump Rate.

gpm

IObtain from Cilcolating System I Options r- Use RougiYless

r

Pipe

Annulus

in

~

Include Tool J Olnt Piem.re Losses

r

Include Back Pressure

r

L

Include Mud Temperature Effects

Tme ol uruatiorr

r

9.00

hi

Returns at Sea Flool Sea Water Density f

psi

Back Pressure:

v

in

•

ppg

Include Cuttings Loading

~ Use String Edito1 Bit Nozzles

Nozzles...

OK

Cancel

I ___J _H~~

a. The Maximum System Pressure and Maximum Pump Power can be entered, or they can come from the active pump o n the Case > Circulating System tabs. To use the pressures specified on the Circul ating System tabs, click Obtain from

Circulating System. 34. Use View> Plot> Pressure Loss plot. The system pressure losses are too high. Notice that at a 615 gpm flow rate, the system pressure losses are in the "red zone."

3-44




The " red zone" on the Pressure Loss plot is defined as the minimum between the pump pressure and the circu lating system rating.

lEOENO Sywl. . Pt-oi.-w ,......_ --~-~-Slrng Pl-.n L.ooo •• ,......_ ArnM "'"""•Lonvo ~ SI Pt_,o IMa w ,...... ""'" -

7000

6000

~SOOD

~

~

4000

~

0.. 3000

2000

1000

480

soc

520

540

580

600

660

820

Pump Rate (gpmJ

P

680

700

l•...i..do Mudl_ot.. oEffeeu

lsoo



120

h

3-45


35. Using Case> Circulating System, change from the 5,660 psi pump to the 7 ,500 psi pump.

Ip!

rBJ

Circul1tting Syslem

I

S.Sface Equpment r-\Jd Pu"nps "'-'cl Pits + Erwrorment

Acbve

Punp N11me

Pl GARD P2GAAD PJGAAD

VoVStk (ga/stkl

3.394 3394 4.740

M"""""11 Mamun Hou Oischo!ll et Speed Preuure Rl!Mg (spm) ~) tl1;>)

VoUneb1c

M~

Efficiency Punp Rote (%) (gpm)

115.00 7500.00 200l.00 115.00 7500.00 200l.OO 115.00 !i660.00 200l.OO

3708

95.00 95.00 95.00

3708

5179

Click Obtain from Circulating System to update the Pumping Constraints based on the pump you selected.

PunpRat~

Purr(llr1Q Consllaoits

Mirwn.im Punp Rate.

lm.o

Iner~ P~ Rate.

Ma>irum Punp Rote

gpm

M,,,.,,...,, Surface Pr"e$wre

j7500oo

p$i

jso.o

win

Mamun Punp Power

12000.00

hp

fns.o

gpm

l

M""'1Ull ~ Punp R111e

gpm

IQbt.., horn uetAatlng S)'Slem I

Optoono ~

f Use Roughneu

-., I At'wUn

Q

Inc~ Tool Joont Pressure Los-

r

fncklde Back Plessure Back Pressure

...

Time

r

Returns el Sea Floo<

Nozzles

J ~-j ~ancet I

3-46

ppg

)

lndude Cuttngs Loading

Bt Nozzles

J9.00

Sea Water Oens~

p$1

Q Use String Edlor

';i lnclde Mud Temperaiure Effects



Applji

I

Help


36. No, there is not a problem.

LEGEND

-

--~oce\M>rmg-Pfenu'e

Syitem Presiu-e t.oas vs P\rrf> Rete

-S1mgPreu<1elossV$

~Rate

AmJus-....e L.ocs vs. Puo1"4) Riie

Bl

Pr-• Lou vs ""'1p Rate 6000

~

.9: CJ)

l!:

4000

-' ~

~

£ 2000 0

460

480

500

520

540

560

580

600

620

640

660

680

700

120

140

760

Pump Rate (gpm)

T•••><>IC<-

lsoo

37. Access View > Plot > Annular Velocity.



3-47


a. Yes, there is turbulent flow around the bottomhole assembly. Any flow rate with an annular velocity greater than the Critical Velocity (red curve on plot) is in turbulent fl ow.

2000

4000

6000

g g>

801)0

Ol °' 5

10000

~

e

~ i.5

12000

14000

18000

20000 40

50

60

70

80

90

100

110

120

130

140

Annular Ve1oc1ly (ftfmin)

150

160

170

190

ISO

2GO

210

b. Based on the flow rates and increments we are analyzing, 575 gpm is the maximum flow rate without turbulence. Use the Rescale toolbar icon ( 19. j) to enlarge a particular area of the plot, if necessary. You can also review the data in grid form by clicking the Grid View toolbar icon ( n:,jj).

3-48




c. Use View> Plot> Annular Pump Rate . Over 2400 gpm would be required for turbul ent flow in the ri ser. 834 gpm is required for turbulent flow in the open hole, and 873 gpm in the cased hole.

1 - ~~-t 2000

4000

8000

g g'

~ OI !5 'ii

8000

10000

4)

....

~

12COO

c:s uooo 18000

18000

20000 &00

700

800

900

1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500

Pump Rate (gpm)

38. Save your data to the database.

Determine Required Horsepower 39. Check the required horsepower using the Parameter> Rate dial og box of the Pressure: Pump Rate Fixed analysis mode. Use the Mode pull-down list to select the analysis mode.



3-49


a. The stand pipe pressure is 5,982 psi, which is less than the 7 ,500 psi of the pump. DEi

P' Rate QU1Ck Look

Pt.mp Data funpRate. Maiamum S1..1face Pres;ure M<'ll
1615.ct

gpm

Stand P"ipe Pre$$!.le:

jro1 1~

p$t

17500.oo

p$t

S1..1face Equip. PretNe Lcm:

j100.oo

PSI

1200100

hp

Bt Prem.te Lon·

1864 69

PSI

Bt Impact Fcxce:

11163.6

bl

Bit Hydrauic Powet

1310 21

hp

Percent Power at Bit

114.38

%

MaximumAJowable Pump Rate

gpm Obtai1 from CicUat!ng System

I

Op1iom Pipe

r P'

r

HSI

l2s

hp/in'

Include ToolJornt P1em.ie Lonei

Bt Nozzle V eloctt,y

1264.7

ftls

lrcl.Jde Back Prestt..1e

ECO at Shoe.

11393

ppg

ECO at Bit

113.95

ppg

in

Use Roughnett

Back Preuure.

P'

rn

pst

Include Mud Temperatl.fe Effet:U

I

Time ol Cvculation: 9.00

r

Annulus

hr

Sea 'Water Den$j(y

I

ppg

ls1s.o

Pl.mp Rate

r


P'

Use Sting E~cx Bit Nozzles

gpm

Nozzles ••

OK

3-50

ri

Total Bil Flow Alea(local)

Retums at Sea Flocx

C«1cel



Help


b. Using View> Pie Charts> Power Losses> Drill String and View > Pie Charts > Power Losses > Annulus to review the power losses in the drillstring and annulus, which are greater than the pump power of 2,000 hp.

Total Power Losses= 2083.44 hp I

1 4 .0~

1. 0rill'ipt(W"90hp)

°"'

2

l'ipt (0711.78 hp)

3 Huvy Wtl\lht Drill Plpo (15 lehp)

I 4. Mecl\Woll ..tar~ 15 hp) I 5. Hnvy Wtigl'l Dri1 Pipe (7H1 hp)

I o. Dril eoa.r (210.61 hp) 1 1. n . - - S t - ( 3.00hp)

I a

Drill c..t>r ( 18.00 hp)

g, lnlep -

St• bili:tt (3.ilO hj>)

I 10 . llon·t.t>g Drill Cob< (18 .03 r,p) I 11.

"-.P ec.dt StlOill:tr (3.00 hp)

12. ,,..D Tool (51 44 hp)

I 13 Ruu>e<..- s..b (1) 70 hp) 14.

a.... Housing (60.41 hp)

1~ .

C-• OnrQ .
I 10. Tri·C.,... st Gll0.21 hp)

Total P wer Losses = 38.26 h I

1 Drill Pipe (13 87 hp) 2. Dnll P ipe (2 1.75 hp) 3. Hea...,.Weight Drill Pipe

38.3'1'

(0.1 3 hp)

I

4. Mechanical J ar (0.04 hp)

I

5 Hea...,. w etght Drill Pipe

I

6. Drill Collar (1.70 hp)

I

8. Drill Collar (0.18 hp)

(0.49 hp)

I 9

Integral Blade Stabilizer

(0.01 hp) 1 0. Non-Mag Dnll Collar (0.09 hp)

WELLPLAN™ Software Release 5000. 1.1 0 Training Manual


3-51


c.

Using View> Pie Charts> Pressure Losses> Drill String and View > Pie Charts > Pressure Losses > Annulus, review the pressure losses in the drillstring and annulus, which are less than the pump pressure.

Total Pressure Losses= 5807.50 psi I

1. llltl ~(1S27.24psi)

2. llltl

~ (!~.~

pti)

3 . HHwy w.;gt"l Crill Pipo (42 :IS psi)

1 4. ......,_.. JJ<(12.G1 psi) I 6. He. .y W.iQl'C Ori1 Pip< (221.61 psi)

I

o. Dlill c..iw (754.03 psi)

I 7. lllltgr>l Bbde St-er('837 psi) I

8. Dril Colar (50.26 psi)

0. lnloP Bbde S t -er ('8.37 P")

I 10 Hon-Mio D1i11 Colar (51.GJ psi) I 1I lotep 91ad• Stabll.!tr ('8.37 psi) 12. MINO Tool (143.30 psi)

I

13 R4S1riet0< Sub (2.11 psi) 14 , e....

1iou
15 Ctoss Ovtr (1170 psi)

I 10 Trt.Cono Bit ('804.09 psi)

sure Losses = 106.40 si I

1. Dr!ll Pipe (38.42 psi) 2. Drill Pipe (60.62 ps1)

3. HeiNfWe1oht Drill Pipe (0.35 psi)

I

4. Mechanical Jar (0.12 psQ

I 5. HeiNfWelght Drill Pipe (1.36 psi)

I

6. Drill Collar (U 4 psi)

I

8. Drill Collar (0.51 psi)

I 9. Integral Blade Stabilizer (0.03 psi)

o.

1 Non- Mag Drill Collar (0.25 psi)

3-52




d. Use Case > Circulating System > Mud Pumps to activate the other pump. (Check the check box next to the pump name to activate it.) Click Obtain from Circulating System on the Parameter> Rate dialog box to include the second pump in the analysis. e. Clear the status messages by tight-clicki ng in the status message area and selecting Clear.

Check ECDs 40. a. Use the View> Plot> Circulating Pressure vs. Depth plot. The annular pressure is within the pore and fracture pressure in the open hole secti on .. LE OE NO

-

-·

-...Pl.rnp&o1-~. System Pressure l - vo ~Rote

-=~~~~ Be Pressuel.OS4vs. """"Ret•

6000

DI" 5000

B

~

a; 4000 ~ ~ a..

3000

2000

1000

480

500

520

5•0

560

580

600

620

Pump Rate (gpm)



640

&60

680

700

720

3-53


b. The View > Plot > ECD vs. Depth plot indicates the ECD remains within the pore pressure and fracture gradient boundaries in the open hole section.

LEOENO

-a---~ Pore - • -Free 20UO 4000 600U ~

8000

Q)

0

~

iii

~ ::E

10000 12000 14000

16000 18000 20000

10

11

12

13

15

ECD(ppg)

c. Hide the pore and fracture pressure curves displayed on the plot by right-clicking the curve and selecting Hide from the rightclick menu. d. Right-click the ECD curve and select Freeze Line from the menu. Change the line color and thickness usi ng the displayed dialog box. e. Click OK to close the Parameter> Rate dialog box. The ECO vs. Depth plot will automatically be updated.

3-54




f.

Refer back to the ECO vs. Depth plot and notice the difference in the curves. This occurs because s uspended cuttings are now included in the analysis. There would be a larger difference if there was a cuttings bed in the annulus.

2000

cooo 6000

g g>

m g>

8000

10000

0

Oj

e 12000

!§ (/)

0

H OOD 16000 18000 20000 13.850 13860 13 870 13.880 13890 13900 13 910 13920 13 930 13940 13 950 13.960 13-970 13 980 13 990 14000

ECO (ppg)



3-55


Bit Optimization 4 1. Access the Optimizati o n Planning analysis mode using the Mode pull -down list. Specify the fo ll owing analysis parameters using Parameter> Solution Constraints. To optim ize based on Bit Impact Force or H HP, you need three I 5/32nd nozzles.

I~

M--.rn Surface Prem.re

17500 00

P11

Nt.rnbel ol B• nozzle•

3

Mamun Pwip Powei

f400o 00

~

Mrwrun B• nOlzlo S~

-1~ 4 - - - 32nd'.

"===-==---if---

Mrwrun AmWr Veloaty MaianunAlowable

P~ Rate

Oblari from C.C<.llatrog SYttem

~00- Z

ft/min Peicet14 PresSl.le Lou ti. Bt

120 0

gpm

~I

j10o 00

IAlowable Bt Flow

I

Options

Iv

I

UseA~

lnc:Ule Tool Jori Presue lost es

I

l'I

I

1'1

r

Abo T.m.Aerl. Flow ... 4tle Am.An

Quick look S•n~Preuure

601390 BtJet

Impact F01ce 6254 -

P1I

Hyadc HOl•ej)()Wel6254

NOlzie Velocity 6254

Nonles No xlO 13

x 15

(3 .~

[3

x15

~lozzles No xlO

xJ

!

xi

l l

•I •I

I I I

· • ·

Nomeo

No x fD

Nonie$ No. x 10

Peicenl Pr8S$Ule Lost
5990

32nd"

.

32nd"

I

·

32nd"

r0513

jo513

HSI·

!s.7

rs1

.

ft/ml'I

Percent Prenue Lou al B~

57

32nd''

;

Opli!un TFA:

10513

lP"

p x14 I ·

!rno

rl

tss

f-c>[rl 1sooo

%

.•

42. Access the Pressure: Pump Rate Fixed analys is mode using the pull-down list. 43. Use the Parameter> Rate di alog box.

3-56




a. The HSI is 2.6 hp/in2 using the c un-ent string nozzles.

DD

t>" Rate

Ql.ick Look

f>l6llP Data f>l6llP Aale

ls1s.Q

gpm

Stand Pipe Presue

Maianun SUifate Preiue

17500.00

p$I

Surface Equip P1eu1.11e Lon: 1100 00

psi

Maxi-run PUITlP Powet

1400100

hp

Bt Prenure Loss·

PSI

I

1864 69

Mlll
gpm

Bt Impact Force

j1163.6

bf

Bt Hychullc Power

j310 21

hp

Percent Power at Brt

113.60

~

HSI:

12.6

hpfrf

Obtain from CicU.alng Sy;tem

I

Options Pipe

j6356.84

Annulus

psi

r

Use Roughness

P

Include Tool Joint Pressure Losses

Bt Nozzle Veloc•y

j264 7

ft/s

r

Include Back Pressuie

ECO

at Shoe ECO ate-

11397

ppg

11400

ppg

Back Prem.we

r

PSI

Include Mud T~alUle Effects Tme ol Ciclktion:

r

I

hf

I

"

Total B- Flow Aiea(Local~

AelUlnS al Sea Floor

Sea Wile. Oensay

P P

in

n

)

ppg

js1so

PumpRale

gpm

~Data ••

Include OJtngs Loadng Use Strng Edrtor Bil Nantes

Nozzles.••

OK

Help

C4ncel

b. Click Nozzles to specify the nozzle size using the Local tab. The String tab indicates the nozzles used on the String Editor. The TFA is 0.518 in 2. 1 1

1'

1'11~

Bil Non les

stmo

Local I

NozlloSizei

N....-ber

GIOl4> 111 GrOUPlll GIOUP 113 GrOUP ~

Sae

p - fis- 32hcf'

r - r - 32ncf· r - r - 32nd· r - r - 32ncf·

Totol Flow Area

%tfOZ21e Area P\.gged

r-- %

I oto1 Flow Area.

~ rl

Coiiii to Stmg



3.57


c.

Be sure to uncheck the Use String Editor Bit Nozzles check box. The HSI is now 5.5 hp/i n2 .

DEi

'P Rate

Quick Look

Plrnp Data Plrnp Rate:

1615.0

!P1l

Stand~ Preuue

Maxm.rn S1.1face Piessu-e

1750000

psi

S1.1face Equp Piemie Lou 110000

psi

Mamun Plrnp Powei

14lXXl.OO

hp

Bil Piem.re Loss·

1179303

p$I

Mamun Alowable Plrnp Rate.

I

!P1l

Bttl~ FOlce

11675 6

Iii

Btt Hydr.dc Powei

ls.4325

hp

Peicenl Powei at Btt

124 61

%

HSI:

ls.s

hp/irf

Pipe

Annulus

p$I

r

Use Aoughne$s

~

Incl.de Tool J~ PresS\.le Losses

Bit Nozzle Velocity

13811

lt/s

C

Incl.de Back PleSS\.le

ECO at Shoe

11397

ppg

ECO a1Bt

lu oo

ppg

in

Back Preiue

r r

11"1

psi

Incl.de Mud Tempeiat1.1e Effects Tme ol Circ\khon

I

hi

Total Bit Flow Aiea(Local)

lo.51B

'12

P~Rate

Isis o

!P1l

Retuins al Sea Floor Sea Watei Density

I

~

Include C~s Loading

r:i

Use Stmg EditOI Btt Nozzles

ppg

Analy$is Data •

OK

3 -58

1728517

Cancel

~



Heb


d. Using the Rate dialog box, notice the stand pipe pressure is close to the maximum pump pressure (7 ,500 psi ), so use three l 6/ 32nd nozzles instead. To use the three l6/32nd nozzles, click Nozzles and specify this nozzle configuration on the Local tab. The HSI is now 4.2 hp/in 2.

6 Ef

'P Rate Qlick Look

Pll'llP Data Pump Rate:

1615.0

gpm

Stand Pipe Prem1e:

Maxlllll.nl S1.1face Pressure:

17500.00

psi

S1.1face Equip. Pretture Loss: 1100.00

psi

MaxlrlUl'l Pump Power

14000.00

hp

I

Bit Pressure Loss:

j138507

psi

Maxirrun AllowMle PllnP Rate:

gpm

Bitl~Force:

11472.7

lbf

Bit Hydrauic Power

1496.89

hp

Percent Powei at Bit:

120.14

%

HSI.

J4.2

hp/g,i

P' lncUde Tool Joint Pressure Losses

Bii Nozzle Velocity:

1335.0

ft/s

r

ECO at Shoe.

J1397

ppg

ECO at Bit.

11 4.00

ppg

Obtain from CirCl.iating System j Options Pipe

r Use Aougmess

r

in

lnclJde Back Pressure psi

Incl.Ide Mud Temperalure Effects

Tme of Ciculatiorl

I

""

f'j Aett.rns at Sea Flool Sea Watet Density

I

Total Bit Flow Atea(Local)

10.589

ii

Pt.mp Rate.

1615.0

gpm

ppg

P' Include Cuttrigs Loacing

r

PSI

Annulus

in

Back Pressure.

jssn.21

Analys1$ Data...

Use String Editor Bit Nozzles

Nozzles...

OK

Cancel

Apply

Help

e. Click Copy to String on the Bit Nozzles > Local tab to copy these nozzles to the String Editor.



3-59


Final Design Check 44. Select the Hole Cleaning Operational analysis mode using the Mode pull-down list. Review the View> Plot> Hole Cleaning Operational plot. There do not appear to be any issues.

l EGE NO -

lncinatm

ITevef • 100 Ill! ,

LEGEND

Llr"IE! • 600.on -

-

-

~~-----'

O

SUspended Vaune

- Total Vaune

4000

g

5.

6000 8000

Q)

0

"O

~

10000

:;J

~ 12000

r

Q)

~

14000 16000 18000 20000

.........~........~.................. 0

20

40

Inclination(•)

60

400

•••

3-60

500

600

700

Minimum Flowrate (gpm)

'

•

••

•

••

0.950

1.000

Volume(%)

1 050

-4

-2

j



-0

2

Bed Height (in)

4


45. Select the Pressure: Pump Rate Fixed analysis mode using the Mode pull-down list. Review the View> Plot> Circulating Pressure vs. Depth plot. There do not appear to be any issues . LfOfNO ~Stmg

~-~ A

- 1-

l:!!~!J!!l~"~.::::::i=:=::::t:============::;t====:;:::==::::====i=====+===:::;:::::i

f'rec

el"'"""• Loso; 138$»7 (pot) coco

g

6000

c: °'

tA

8000

O>

§

10000

«i Q)

g

12000

«l

tij

0

HOOD

16000 18000 20000

-r1000

2000

3000

4000

5000

6000

7000

8000

9000

I 0000

11000

12000

Circulating Pressure (psi)

r... .,~ 16877 21



..

3-61


46. Access the View > Plot> ECD vs. Depth plot. There do not appear to be any issues.

LE O f NI)

--ArWUA o Pore

- A - Frac

2000 4000

6000

g g'

8000

Ui

l?

10000

0

-ro

e 12000 c:

~ c5

14000

16000

20000

7 00

7.50

800

8.50

900

9.50

1000

10.50

11 00

11.50

ECD(ppg)

3-62

12 00

12.50

1300

1350

uoo 14 50 15 00




Analyze Surge/Swab Pressures and ECDs (Using the Surge Module) Input and Review Well Configuration and Analysis Options 47. Access Surge analysis using the

lail toolbar icon.

48. Use Case >Pore Pressure to review the pore pressures. The over pressured zone is at 10,743.8 ft TYO. Press FU to access the Convert Depth/EMW dialog box. Specify the TYO, and click Convert to determine the MD. Ip'

[El

Convert Deplh/EMW Depths fol) 'ft)

I 10743.8

Pressu"e (psi)

EMW(PPO)

Pressure(EMW Pore Pressu-e Fracture

r

I

T\'O {ft)

I 1sooo.1 7395.09

13.25

l"ii301.62

14.88

~

J

I

Open Hole PresSU'e Lmts

PresSU'e (psi) ~x.

Pore

MWJ. Fr«ture

9287.80

TVO(ft) 13243.71

7274.45

9193.713



3-63


Analyze Transient Responses Tripping Out Operation 49. Specify operations data using the Parameter> Operations Data dialog box.

@tBJ

IP Operation Data: Swab/Surge OpetatlOO

r

Surge

r. Swab

PipeDetaib Shoe Depth (MD)

125000

ft

VleA TO IMO)

200XJO

ft

Adciional MD ol lnteiest

J15(XXJ.0

ft

Length ol Stand~

1~.00

ft

~ Acceje(&toon

J2.lm

~ Oecele(!>i.m

ft/sec> IVsec>

Addtional 0 pbons

r

MOVJng Pipe 1110ft 1 f125000

1210.0

fVllW"I

2. ll&mO

ft

12100

ftll!W"I

3 l200XJ.O

ft

1210.0

4

ft

ft/l!W"I

ft

ft/l!W"I

5

P!!!!Speed

ft/l!W"I

- Pipe Depth st-.Ud be.., ascencing 0
Flow Details

Use low Clea
r E!
Fluid Ecil0<

v !rd.Ide Mud T~e
Cancel

Apply

~ gpm Help

50. Use the View > Operations Plot> Transient Response plot to review pressures or EMW vs. Time. Use the right-click menu to select the correct plot.

3-64




a.

?"""T1.oru..n1Re•porn~ . w.. oep1h 0

Yes, there is a problem because the Pressure when the moving pipe depth is at TD falls below the pore pressure, as denoted by the green line on the plot.

200ll011

_

__

_ _

__ _

0.600

0.650

_

LEGEND -e-125000 tt - 2roo nmri 0 1S000.0 ti - 270.0 ftAM ~ 20000.0 It - 270 0 flknin

9500

9450

iii

8:

9400 .....

ii! (/)

a:

9350

9300

9250

0.000

0.050

0.100

0 150

0.200

0.250

0.300

0.350

0.400

0.450

0.500

0.550

Time (min)

b. About 10 psi.



3-65


51 . Access Optimized Trip Schedule (View> Operation Plot> Optimized Trip Schedule). The recommended safe trip speed is 150 ft/min .

LEOENO Tr-.,Speed

-

14000

g

15000

~ Q)

a

"O

16000

~

;:,

"'ro Q)

~ 17000

c:::

;:,

er

18000

19000

20000

Welbore Dept> • 20000 0 ft

H6

148

150

152

154

Tnp Speed (rt/min)

20000

Welbore Doph • 20000D ft

6000 Mri'run Trip Speed !1so.o

3-66

ft/rrwn

M_,..,.,, Tnp Speed

fi'5UO ft/rrwn

7000

8000

Pressure (psi)



9000

10000


52. Specify the trip speed using Parameter > Operations Data dialog box. Use View > Operation Plot > TransientResponse Plot to review results at all depths. Re fer back to the Operations Data dialog box, use 150 ft/min for the trip speed, and notice the issue is resolved. IP Opercstion Data: Swab/Surge

~

-

OpetallCn

r s..ge

r. swat.

?tie Oetais Shoe Depth (MDJ

Mov~PipoMO

1125000 2000)0

WelTD(MDJ

1 j125000 fl

Additional MO ol h"llerest Lenglh ol Stand ?tie ?tie Acceletation

!!Kl 00

- - It

j1so.o

lt/mon

3 1200))0

fl

j1so.o

fVrlllfl

5

ft

rt/l!Wl

fl/see

Addibon.o!I 0pbon$

·

r Exec:Wln Tme ... be long!

.; lnWde Mud Tempe
OK

0000

~

,.J'.

~

0 050

• •

I

iJ

1

138 ppg 08M. 13.00ppg

la.o

Flow Aale

•

ascencfng ordel

- FUdEditor J C.c.Aatrog F\.od

_,;'";

rt/l!Wl

~Depth~ be n

Flow Det411t

r Use Low Clearance~·

lt/mn

2 (1500>0

ft 11/aee'

~ Decelerabon

~Speed

j1so.o

ft

CMcel

!PTI Help

"

0 100

0 150

0.200

0 250

0 300 0 350 T1me(mtn)



0400

0 450

0500

0550

0.600

0.650

3-67

)


Tripping In Operation 53. Use Parameter> Operations Data to change the operation from swab to surge. 54. Use View > Operation Plot > Transient Response. The calculations cannot be performed for a s urge operation when a moving pipe depth is at TD. The maximum moving pipe depth allowed is TD minus one stand length. In this example, the maximum moving pipe depth would be 19,910 ft. 55. Use Parameter> Operations Data to change the moving pipe depth. There are no predicted problems. ~(g)

'"' Opcralion Oala: Swab/Surge Operation r. Surge

r

S....t>

PirieDetaila Shoe Depth (MD)

j12500.0

It

\I/el TO (MO)

f200XJ 0

It

Addlional MO ol lnterett

j-1500l. -O - - It

L~h ol Stand Pipe

f90.00

ft

Pipe Ac:c8eletJon

12.CXXl

ft/tee'

Pipe OeceleretJon

l2.CXXl

ft/tea

Movng Pipe Mo-

Pipe Speed

1 112500 0

j150.0

ft/nw1

2 11500)0

j1500

ft/nw1

1150.0

fl/l!WI

3 l1 ss10.o 5

ft It

Mnon

ft

IVnw1

-Pipe Depth snoudbe"' ~ 0
Addibonol Optiona

FlowDelolli

r Use Low 0-«>ee ~s· r E>
-~~

P Include Mud T~eture Eflectt

C.c\MtJl!IAt.:I Flow Rate

,13. _B_ ppg _OBM-.1-3.00ppg ---::i~

jo.o

OK

3-68



IP" Help


56. Yes, it is possible to experience both. The following plot from another analysis displays both surge and swab effects.

The line in the middle of this plot was added to the manual to illustrate the surge (above the line) and swab (below the line) pressure responses.

68-40

6$10

ijl B

Ill 6820

.,5

"' 6810 ~

CL

6800

6190

6180

5710 8780 · 0.050 0.000 0050 0 100 0 150 0200 0250 0300 0350 OCOO O CS-0 05-00 0.550 0600 0650 0700 0.750 0600 0850

T1me(mm)

The conventional definition of surge operations is operations that have increases in pressure only. Transient models can predict both surge and swab pressures while running in the wellbore. Transient models have been validated using downhole tools. Refer to the online help for a list of technical references. The WELLPLAN Hydraulics module has a steady-state (not transient) surge/ swab analysis.



3-69


Investigate Well Control (Using the Well Control Analysis Module) Input and Review Well Configuration and Analysis Options 57. Activate the Well Control Analysis module using the tool bar icon.

I£-

58. Review geothermal data using Case > Geothermal Gradient. Ip!

(1)r8]

Geothermal Gradient

I

I

standard Aclditlonal Plot

Tempeioture ot W'e4I TYO

r

r_.el\Jre@ j132437

r.

Orerdert

OK

3-70

n

~ ·F ~

J_

·Fn
~

J




59. Use Case> Well Control Setup. (ll~

'P Well Control Setup

Choke/kl Lne

I

r Speciy ChCJkeJl
'"I- - -

pa

OIOkeJKI l.no (" Ctd
• ChctelndKILne

Choke/Kl l.l'IO Lervn

j590 00 13500

Choke l,..10

ft

n

KUinelD -o~ enobled/usod l0t llb•e~ welt""

" Use< enleied aJ( PfeHUIO Ion Wll ovei1.le nt~ c~ed C"' l)feHUle losses

tx>weve "" drnent1ont wol s1• be used IOI olher cabkbont

Cancel

I

~ J

60. Review the temperature model using Parameter >

Temperature Distribution.

11J(g)

~ Temperature Model ,.

St~Slale C.cUatJon

r

Geolhemal Grader¥

r Conuant Temperatu:e

St°*State ucWbon Flow I.re Mud Temperall.re: Flow Rale:

j85.0 j625.0

gpm

Mud D~

j13.90

lll>9

"f

Cormant T~atiae "f

AmJus Mud Temperwe.

OK



Cancel

H~

3-71


61. Use View >Plot> Geothermal Gradient.

1000

4000 6000 9000

g

10000

~ 11000

1' 000 16000

19000

10000

<0

60

90

100

120

1'0

160

180

100

120

Temperature (°F)

Determine Kick Type 62. Use the Parameter> Kick Class Determination dialog box. This is a Kick While Drilling because the kick interval pressure is greater than the circulating bottomhole pressure. Refer to the online help for more information.

1p1

r1JIBJ

Kick Class Determination Setup IOO!ll Mud Gra
!0111

p$111t

Ir.put

CirCIAabotl Flowtate, Kick lntetval Gradiert

1625.o lo.732

(pn

pw'fl

Quick l ook

Kick Closs C.cWlng BHP-

~Kick Whlle 01iling j!617_2 _ _

Stal!c BHP;

!$00 9

Kick lntetval Piesso.R

f9715 3

Undetbalance Kick lnterv.t f206.4

p$1 p$1

psi

psi

OK

3-72




Estimate Influx Volume 63. Access the Parameter> Influx Volume Estimation> Kick Detection Method tab. Flowrate Variation is the detection method used.

[I)IBJ

If" Influx Volume Estimation

r.

flowrele VlWlebon (30 0

r vo1tmo v......ID
!J1fY1

bbl

i-

"""

OK

Flowrate variation detects flow-out increases. Volume variation detects pit volume increases. 64. Access the Parameter > Influx Volume Estimation > Reservoir tab to review the reservoir information. 1p1

Influx Volume Cstimation

Seti.(>

1

Kick Detection Method Reservow

(1](8) Reaction Times I Results I

Pe11neability

1100.00

md

Porotty;

l:io.oo

~

Thk:l<.neu:

1100.0

ft

Rate ol Penetration:

jso.o

ft/hr

Eicposed Heiglt.

r-

I

ft

I

OK

Coroeef

~

J

Note Some fields on the Parameter> Influx Volume Estimation tabs are disabled, depending on the kick type.



3-73


65. Access the Parameter> Influx Volume Estimation> Reaction Times tab to review the reaction time. "" Influx Volume Estimation Setup

I Kkk Detection Method I Reservoor

Close Choke;

lo.2 10.2 10.2 f1.o 10.5 lo.s 102

Total Reaction Tme:

!2.8

Step Rotate:

Pd. Off Bottom;

StopP\.llll flow Check: Open HCA

Close BOP

OK

J~

--

- - -

-

f1][8)

I

Reect:lon Times Resuls

""' ""' ""' ""' min

,,...,

""' ""'

I

~

66. Use the Results tab (Parameter> Influx Volume Estimation> Results) to determine the expected influx volume. It took 260 seconds to detect the expected 5.5 bbl kick. 1p1

~~

Influx Volume hlimalion

Setup

I Kick Oetectiof'I M«hod I Rewvow I Reectoon Trnes

Total lnllu>c VoU11e:

j5:5""

bbl

lnlkn< VoUrie at Detection:

Jl.7

bbl

Detection Tine:

f260

sec

ReS\Ats I

Cancel

Analyze Kick Tolerance 67. Access the Kick Tolerance mode using the Mode pull-down list.

3-74




68. Use the Case> Well Control Setup> Operational tab to specify the method.

[l)[B)

IP- Well Control Setup Choke/Kil Line

Opetotlooal

I

Kill Method

BOP Pl=ure Aatiig

l!XmO

CaulQButslPresslleA~ j10035.0

poi

~ Buiat Safety FactOI

80 00

~

Leak Off Plessllo.

4500

leak Off Mud \Yeoof>l

113.00

OK

Cancel

J

69. Specify the kick tolerance analysis parameters using Parameter>

Kick Tolerance.

[1JfBJ

tr~ Kick Tolerdnce fnpoJ

Setup

Kick Clas$

'~l~l::!:Hl:~

Tweollrfu><

jGas

Kick lnte
19n53 !nm

p$1

f NU< GIa
r

pw'1I

Kil Rate

j135.0

Totaf lnflo< Valme

j50.0

bbl

Depth ol lnletMt

ji2500.0

ft

psVtt

Kil Mud Gra
jo.m

pu/fl

p$1/f\

Depth lnletVaf lo Check.

17500.0

fl

fr>t;.,j Mud Gradenl

SwabAllalym Optioru

r ("

om

m:.

l ~ce1 '

::J psi/ft gpm

~~elp

J

70. Analyze kick tolerance results.



3-75


a. Use the View> Plot> Allowable Kick Volume plot. The maximum allowable influx volume is 55.4 bbls.

LEGEND

-

Mu.sPressure

0

10

20

30

40

50

60

10

80

90

1nnux Volume (bbl)

3-76



100


b. Use the View> Plot> Pressure at Depth plot at the shoe. The pressure is between the pore and fracture pressures while the kick is circulated out. LE OE NO

-

Arn.Aasf'r"....-e

1200

70()0

8900

~

6600

iii ~

~

6400

"'e a..

6200

tn

6000

5900

5800

200

400

800

800

I 0()0

1200

1400

1600

t 800

2000

2200

2400

2800

Volume Pumped (bbl)

Use the right-c lick menu to select the correct plot, if necessary.



3-77


c.

Use the View> Plot> Pressure at Depth plot to analyze the annular pressure at the surface. Use the right-click menu to select the correct plot. The highest choke pressure is 134 1 psi.

UOEND

-+- ...,.,..,. Prenu"e 1300 1200 1100 1000 900

~ 800

s ~ "'"'

700

I/)

£

600 500 400 300 200 100

200

3-78

400

600

800

1000

1200

H OO

1600

Volume Pumped (bbl)

1800

2000

2200

2400

WELLPLAN™ Software Release 5000.1 .1 0 Training Manual


2600


d. Review the View > Plot > Maximum Pressure plot. The Maximum Pressure plot displays the maximum annular pressures that will occur at any measured depth with an influx of constant volume in the well. The Pressure at Depth plot displays the pressure at a specified depth of interest in the annulus as the kick is circulated.

13000

14000

g

15000

)(

=>

'.E 0

£ 16000 a. Q)

0 "O

~ ;;;;)

17000

"'«l Q)

:::E

=~

.

0

18000

JO

!

gj

19000

i

20000 5500 5600 5700 5800 5900 6000 6100 6200 6300 6400 0500 6600 6700 6800 6900 7000 7100 7200 7300

Pressure (psi)



3-79


e. Access the View> Plot> Safe Drilling Depth plot. Use this plot to display the maximum pressure at a specified depth of interest, using a constant influx volume occurring at the bit as the wellbore depth increases. The analysis begins at the last casing shoe depth, and continues over the distance specified as the Depth Interval to Check on the Parameter > Kick Tolerance dialog box. (The ending depth of the analysis will be the casing shoe depth plus the Depth Interval to Check.)

13000

14000

S:

ISOOO

)(

~

= & 1eooo 0

~

l

18000

i

19000

~

MOO

3-80

5800

&000

&700

S•OO

Pressure (ps1)

HOO

f800

1000



7200


f.

Access the View> Plot > Formation Breakdown Gradient. This plot displays the maximum pressure (expressed as a gradient) that will occur as a result of the specifi ed influx size.

LEGEND ~-.SPreuue~

o - •

Pc
13000

14000

15000

g .s a.

c3

16000

"O

~ =>

"'lll Q)

::?'

17000

18000

19000

20000

0580

0600

0620

o s•o

oa&o o 680 o100 Pressure Grad1 em (ps11ft)



0 720

0 7'0

0 760

0 780

3-81


g. Use View> Plot> Full Evacuation to Gas. Yes, there will be a problem if there is a full evacuation to gas because the annular pressure exceeds the fracture gradient.

LEGEND

.....

-~. 0 PorePr....,e

- A - froctl.l'e Pte.s~e

MuO L.ne..

s«i.o fl

2000

4000

I

~

.

6000

g 6

8000

...?

10000

~

a:

..2

0. Q)

a

'O

2!

::::>

en

gi

~

12000

..

14000

16000

18000

20000 0

1000

2000

3000

4000

5000

6000

7000

8000

9000

Pressure (psi)

3-82



10000


Use Animation to Review Results 7 1. Use the VCR buttons ( "' .. • .. "' • ) to start, stop, and rewind the animation. The heavy weight mud is in the wellbore and string at the end of the animation. ~1 MI•!., l..il •

I

SdiematcOpllans

ol)IJOl'llToScao

::J

126833

bbl

bbl

lnl'u
loo loo loo

Ode f'lent.te-

11• 70

v......,~

klbc ToPMO

tribe Volrne

590.0 ft

Me.ri Sea Level (100.0 ft) ~(600.0 ft)

Bottom Hole

p,.,.....,

Premte at 0 ¢

('" o.......

1995903 17133.54

r.

"''

"'' ptl

Wlll.M
12500.0 ft

20000.0 ft



3-83


72. Use the Driller's radio button to change the kill method. The light mud is in the wellbore and stri ng at the e nd of the animation.

i.. 14

._I_.__._. . .l_•. . .I

Schematic Op0onc

3.

Op0on To_S_ cale ____

Vokme~

lnlU. Top MO lrfu< Vollne

Mean Sea level (100.0 ft) r.t.dne (600.0 ft)

590.0 ft

!26833

bbl

(oo

mo-

lrfu< Hetghl

roo-

Chol
!213 66

bbl

ft psi

Bottom Hole Ptesue

!9813 Ill

pso

Ptessure at Delllh

I708!i 70

~

,. 'V/111..wl'Vledt

12500.0 ft

20'.XXl.O ft

73. Switch back to the Wait and Weight You can al so use Case> Well Control Setup >Operational) to change the ki ll method.

Generate a Kill Sheet 74. Access the Kill Sheet ana lysis mode using the Mode pull-down list.

3-84




75. Use the Case> Well Control Setup tabs to specify the analysis parameters. /pl

CTJrRI

Well Control Setup

l()petationail siow~ I

Choke/Kil llne Choke/Ki Lne.

r

Choke U1e ()rtf

t: Choke end Kl Lne

Choke/Ki Lwie Leniith: 1593.00

It

Choke Line ID:

n

13.500

l'l

Cancel

OK

/pf

j

Apply

CTJfB)

Well Control Selup

Choke/Kil lne Operational j Slow PlMnps I

Kil Method

r

Drier's

!100XJ.O

psi

Casing e..n t Preuure A!lliig 110035.0

psi

Camg Burst Safety Factoc

100.00

~

Leak Off Pret$\lle:

14&1.0

psi

Luk Off Mud Weit;#.

113.80

ppg

BOP Pre=se Raling;

OK



3-85


76. Click the I ~ toolbar icon to access the Notebook module and Miscellaneous mode. Use the Parameter> Leak Off Test dialog box to specify the test pressure as 450 psi. ~ leak Offlest

(1)(E}

Input MudO~

113.80

PP!l

TMl freSSUfe

1450.0

PSI

IYO

IS49la

It

/:It GllP

1100.0

ft

.Su Depth

lsoo.o

It

OIAput

Form Break. Press p255.9

PSI

'o.764

pW!t

Form. Break. Grad .• 1o. ~

p:illt

Equv Mud Grad!

Clo;e

H~

a. Use the mud density of the active fluid on the Case> Fluid Editor. b. The leak-off test was performed at the casing shoe. The casing shoe measured depth is 12,500 ft. Use the Convert Depth/EMW tool (press Fll) to determine the TVD (9493.8 ft) .

(g}

IP Convert Oepth/£MW Depths lo'[) {rt)

TYO {ft) 19193.8

PtesS\.re (psr)

EfflW 11. 1s

j 12500

PtesSlJ"e/EMW Pore PtesS\.re Fracttte

5198.99

1727M5

r

I

-~

!10s

Open Hole PresSU>e Lmts

3-86

PtesSlJ"e

<¢1 lm1.eo

M>j ft)

Max. Pore Mn. Fracrure

lmMS

19193.78

13213.71




c.

Use the Reference Datum section of the Well Explorer to determine the air gap and sea depth.

Trannq Rig Cf

100.Cft 100.cxit

o.tl6n Otv.tion:

I "' Gc> (MSl): Level Me.vi~

I.........

~ Olpth (HSI.):

500.00ft

~

600.
d. The calculated equivalent mud gradient is the same as the fracture gradient.

I&

toolbar 77. Activate the Well Control Analysis module using the icon, and the Kill Sheet mode using the Mode pull-down list. 78. Use Case> Well Control Setup to review the slow pump information.

1p1

l'.1)~

Well Conlrol Setup

Vcbne/Sboke ~stk)

Speed (spm)

40.00 20.00

3.394 3.394

1. Pl GARDENER

2. P2 GARDENER

1

~~~~~~~-_J QI(

Cancel

I

Apply



_J

~

3-87


79. Access Parameter> Kill Sheet and specify a 6 bbl pit gain. C lick Select Pump/Kill Speed and select the pump with the 40 spm speed. Notice the other data, including the annulus and string volumes, are already specified. -

Kick p.,ametert

fl

Stu4n Catt>g Pressure

lm:no ls.o Im oo lsoo.oo

Overkll Pressure:

10.00

P*l

Trp M.,gri

10.00

PP!I

MD of Kick. p~ Gain;

SIU~nDPP

Arniui Volo.me

bbl

Leroglh

psi

w

W~Matenal

3

Je..-e

WI. Mall Spec{rc Gray(y 14.500

•ll

Wt. Mall. WefT'. Pef sac1<. J94.oo

lbm

wt. MatJ MllQ Capaciy:

1188

bbl/ft

Tala! Mall Req<.wed.

11058437

fl

bbl/fl

wah Trip M«gin

fl

100239

bllU!t

Kt Mud Weq1t

ft

lo.ms

bbllft

'Wl Mall Per Volo.me

ft

j0.1185

bbl/ft

l5~ 00

Casiig

j11s10oo 17500.oo

It

Qurck Look

Ncmbec d Sacks Total Mall Aeq<.wed-

TCl&IArin..blen¢!

fmno

ft

Totllf Am..llnVoloine

j2600.5

w

bn

[1424 - - ppg 'Oro- ppg r;:;-- .o o.oo lbm

lbm/mn

Stnng Volume

A~

leroglh PumpOetoi> PIJmpName-

ppg

!il76

Tl.Wg;

Open Hole:

ppg

0 7iJ

N\l!'iber of Sodu

Choke• KJI IJne

Ori~

h 424

bbl/ft

rt

p$I

1020.0

~

KJI Mud Weii;#. \Ill Malt p.,vobne

lo.3643 lo.am lo.am

jmoo looo jo.oo

A-

---~

W•tw Tnp M«gin

Defd from Ecitor•

WergtUp Mud Tonk Volume.

--

Siring .ANU.;t Ve>Unet

OPICASflBG/CT 119067 9A [Pl GARDENER-OENVER P>
Volrme.IS~oke

p.334 -- gat/•tk

Speed-

14000

Pre;iu-e.

(75000

VolrneUlc Eff1C1ency.

f9500

Select l'l.lnplKjt Speed

-

spm p$I

%

Capacty

ft 10.0169

bbl/ft

lo.ooe7 lo.IX&!

bbl/ft

Total String length

,200000

ft

Tala! Str11gVolrne

(32e7

bbl

Heavy Wei!t'

lmoo

11

o.-.coa..-

1602.lli

ft

bbl/ft

Ql.ICk look

I

a. Barite is the weighting material. You can select other materi als using the pull-down list. b. The shut-in casing pressure is 500 psi. Note You can click Default from Editors to default the annulus and string volumes based on data input in the Case> Hole Section E ditor and the Case> String Editor when performing future analysis.

3 -88




80. Access View > Plot> Kill Graph.

lfOfNO -

9r<*e:t¥t:~• · 8511.

10•0

1020 1000 9BO

780

500

100(1

• 500

2000

2500

Number of Strokes

3000

•ooo

8 1. Pump efficiency makes a difference. a. Freeze the current line on the plot.


)


3-89


b. Use Case > Circulating System > Mud Pumps to change the pump efficiency for pump #1 to 90%. 1p1

Pt.mp Nome

P1 GARO P2GARO P3GARO

3-90

rEJ

Circulating System

Vol/Stk (gtil/itl\)

1394 1394 4.740

M d)CllTU1\

Speed (spm)

Ma>CllW1\ Hon

Ooschar Preuu-e (psi)

e<

A.mg (hp]

115.00 750000 200!.00 115.00 7500 00 200!.00 11500 566000 200100

VoUnel.ric ~ Etfiaency Pt.mp Rote (%) (gpm)

90. 95.00 9500




c. Compare the two curves on the Kill Graph. Pump efficiency does make a difference. It will take more strokes with a less efficient pump.

lEQ ENO Sllt
- ~.,, Pr.....-.

1040 1020 1000 i80

180

500

1000

MOO

AOOO

ma

d. Set the pump efficiency back to 95%.

82. Access the View > Report and select Kill Sheet. Click Preview to view the report. a. Cli ck Report Options to review the options. b. 1176 sacks of weighting material are required. 3.4

Kill Mud Weight Up Overkill Pre$aure Weight Increase

Number of sacka

O 00 psi Kiit Mud weight

0 44 ppg wt Matt required per volume 1,176 Total wt. Mall. Required



14 24 ppg 070ppg 110,584 37 lbm

3-91


c. The fi nal c ircul ating pressure is 774 ps i.

d . It takes 4 ,28 1 strokes and 107 minutes to fi ll the string.

.._ ••"""Mfti" ·~.........

-('1111..

-··-

, ........_!_.......

I

,~._.,

__.!!_

3-92

,..,, .,....,

..,._ ,..,. ~1

,_,_.,_

~

·~ ••

•

1111

II

;u1:0 M.J :Qo.J'

~

,,,.i f'

.•

,'.:;: J

,_

IOID

,..,~

~.

am ..!!._•

,.

1110

-· ..

~

WELL PLAN ™ Software Release 5000. 1. 10 Training Manual


II


Determine Critical Rotational Speeds (Using Critical Speed Module) Input Analysis Parameters 83. Access the Critical Speed module by clicking the

G

toolbar icon.

84. Use Parameter> Analysis Parameters to input the following parameters: fP

CTJ(8)

Critical Speed Analysis Parameters ParMleters !OIC1Jll at Bl

120010

1\-bf

~e!ghtonB•

125.0

lop

gpm

Flow Rate

1615.0

Steeiing Tool .(2nentabon

jo.oo

~tarting Speed

120 1200

fndngSpeed Speed!na~

E>
Mesh Begins at Oi$1 From Bit Max Total 1.englh ol Md!

js 1100 jo.oo j9999900

rpm

rpm rpm

ft It

r Qiinamics

I

OK

I

c.r.cei

I

H~

a. You have a tri-cone bit, so you use an excitation frequency of 3. b. Set Mesh to 99999 ft to analyze the entire string. c. Dynamics is not checked, therefore the nodal torque due to friction is not included.



3-93


85. Review the mesh zone parameters (Parameter> CSA Setup). Use the default parameters. '1>' CSA Setup Data

--

-

-

-

Mm Zone Aac>ecl Rabe>!

linoo

Aspect Aabo l

110000

a

Restore Oelds

Lenoth1

lsoooo lsooo

It

L~2

125000

It

Aspect Retoo

[ij(g]

-

I

Somdary ConOlioos

Aadou$

TJlllO

loooo

110000

1000

n

Redus

n

Ar9e

looo

:::J'oooo

T-

""""

(oooo

n

OK

T-i

Aioal

Ar9e

3199000

jo.oo n

C.val

~

H~

a. A mesh is used because it is a finite element analysis. The mesh is a term for describing how the string is divided into elements and nodes prior to performing the finite element analysis. b. The BHA will be divided into elements based on the input values for Aspect Ratio I and Length I. Refer to the online help for more informatio n. c . Aspect Ratio l is the smallest ratio because it is used to mesh the BHA zone (500 ft in this example). Jt is preferable to mesh the BHA into smaller elements. d. Length 2 is used to mesh the section of the string between the BHA and the drill pipe. The remaining pipe will be meshed using Aspect Ratio 3.

3-94

WELLPLAN 7M Software Release 5000.1.10 Training Manual



Examine the Stresses Acting on the Workstring 86. Examine the stresses acting on the workstring. a. 140 rpm and 35 rpm may result in high relative stress in the string (View> Rotational Speed Plots> Resultant Stresses).

1000

2500

~

a

2000

j

ISOO

1000

500

20

30

•O

SO

60

10

90

90

100

110

120

130

140

ISO

160

'70

180

190

200

Rotauonal Speed (rpm)



3-95


b. Use View> Position Plots> Resultant Stresses. At 140 rpm, these stresses are likely to occur 12 ft (mud motor) and 37 ft (MWD) from the bit. (Click the Rescale icon ( 19.j) to enlarge a portion of the plot. Click the Data Reader icon to determine a specific value for a point on the curve.)

q-:- p

3500 -

LfOfND

-~ 3000

lSOO

1500

o

3-96

'i""l~"'l""l' "' I' 2000 Jooo •ooo sooo snoo

1000

'i "'!'" i""i "" l' '" l 11 1000

eooo woo

Distance

"i

11 11

10000 11000 11000 13000 From Bit (It)



i'"'l'" 1 i"

u ooo

15000

uooo

1

1" '

11000


l$0D

--

LlOl!NO

Sc~'

2001>-

' 1 ' '

' 1' ' '' 1 ' ' ' ' 1''''1' ~ "'"1 1 ' ' ' '1 ' '''1'''' 3000

·- - - I -·- ·-

l5il0

AOOO

--

c. These stresses are likely to occur in the mud motor (12 ft) and MWD (37 ft).



3-97


d. Bending stress is causing the high equivalent stress in these components. If necessary, rescale the plot to more easily view the data (View> Position Plots> Stress Components).

---

26001

L fOENO

.........

2• 00

si.e..

1200

2000

1800

16-00

~

.9:

1400

"'"' _g: (j)

1200

1000

800

800

•OO 200

1000

3-98

2000

3000

4000

~

6-000

1000

8000

0000 10000 11000 12000 13000 1'000 15000 16000 11000

D1stante From 81t (ft)




e. The View> Position Plots> Stress Components plot displays the stress components for a range of rotational speeds. The View > Rotational Speed> Stress Components plot displays the stress components at one rotational speed.

--

26oof---~

.....

LfOfHO

2400

-

so''"'""'""

2200

LEOEHD A:l.WSkess

e..qsi...•

,.,,....,....

TOrtirorilt3rtu

2200

1000

2000

1800

1800

1600

1800

u;

.B

~

1400

-

U DO

~

1200

~

1200

1000 1000

800

IOO 800

•OO

200

o

2000

4000

600.0

sooo

uooo ie:ooo

1001)(1 1 2000

180

Otstence From Sit (h1 - - - - - - 1--

-511-.

-



~ """

.11)1)_

--UO.

Ro1
3-99


Examine String Displacements 87. a. Yes, there is more relative displacement at certain rotational speeds. Significant displacement is at 140 rpm, bul 35 rpm and olher speeds also have higher displacements (View> Rotational Speed> Displacements).

L£0ENO

-

v..'llCll(X)CwPile:iemeni

~==n==.wc

l 50

l
30

12'l 110

g1 00

~

E

090

a-

080

~

0

070

06-0 050

040 0 30 0 20 0 lO

2'l

3-100

30

•O

so

60

70

80

90

100

110

120

no

Rotational Sooed (rpm)

1'0

l SO

180



170

180

190

200


b. Display View> Position Plots> Displacement in one vertical pane, and View > Position Plots > Resultant Stresses in the other pane. The MWD is located 30 - 47 ft from the bit. In this interval, both the displacement and resultant stress are at a peak.

Lf Gt;NO

--

v-..oo rrensvene(V) A.VttftQitHd \MttttJ

140

1

20

ll!'O!ND

1 00

·-

- =f:? 9-C-J

otl

121)0

2otl0

teoo

0.20

-GOO

-010

·150

· 100

· SO

0

50

100

Distance From 611(ft)

1SO

200

· 100

·50

0

50

Distance From 6 11 (ft)

100

150

. . . . . . . .~11<0 ...



3 - 101


Review Bending Moments and Shear Stresses 88. Spl it the screen. Display View> Rotational Speed Plots> Moments in one vertical pane, and View > Rotational Speed > Shear Forces in the other. The peaks in these plots correspond to the peaks at 140 rpm and 35 rpm you saw in other plots.

3- 102




Reviewing Results in 3D Plots 89. A 30 plot is a good visual representation of two 20 plots. For example, using the Resultant Equi valent Stress plot, you can determine the equivalent stress as well as the pos ition where the stress occurs.

Rotol 'onol Speed lrp,., )

-

3500 --i---.J

3000

.£'

I

2500 ~

., 0

2000 ~

.,

:(>

lSOo

..

~

'-<'!loo -

s

JOo0o ~ ?$00

sooo

-/J


l

...

J
3-103

Chapter 3 : Drilling Solution

Predict BHA Build and Drop (Using Bottom Hole Assembly Module) Input Analysis Parameters and Review Results 90. Activate the Bottom Hole Assembly analysis module by clicking the Q) J tool bar icon. 91 . Review the mesh zone parameters using Parameter> Mesh Zone. Use the default parameters.

(1](8}

1p1 Mesh Zone

Aspect Ratio l .

'.!20.oo

Aspect Ratio l

1100.00

Aspect Ratio .3:

lsoo.oo

~ength 1

lsoo.o

ft

L~2:

12500.0

fl

OK

3-104

Cancel

Help

J




92. Use Parameter> Analysis to input analysis data and revi ew results. The bit is tilted downward 0.06 degrees. The negative bit force indicates the force is acting downward. Refer to the online help for more information. In the horizontal plane (Direction), the string is aligned with the wellbore. IP BHA Analysis Data

-

Quick Look.fleds at the Bit

Par"'1letet•

l0
120010

fi·l>I

'Ne'ltit on Bt

j12.o

~

Rotary Speed

1120

rpm

Flow Rate

js1s.o

llll'll

r

(1j(g)

-~

f.Mlle Dr~· Steemg Tool Onent

r ~--

jooo

I~

60.00

String

's035

Tit

1035-

F0
1·2210 j22484

St11no

[22478 - - .

fl

Tit

n

F0
f-006 1·111

C$

Foimat>on Har~s;

Ill

'Nelbote

Ori lntervllt

Bit CO
-

Owecbon

Recoid lnteival:

Rate rl Penettation

• + Up/Al!tit. • Downll~t

\t.'elbote

Ill

Build Rate

moo

'/lOCWt

'Wl!lk Rate

0.00

'llCXJt

It/Iv

• DIUlbled d bi not p
Weight On Bit OK



I- ~

H~

3-105


93. Examine the results for drilling ahead 300 ft. Use Parameter> Analysis to input analysis data and review results. Unless noted otherwise, use the same analysis data as in the previous step. 'P BHA Andlysis Oatd

-

Par
- --

QllCk Look·Reds at the Bt

120010 112.o 1120 jsis.o

T01queat Bil

'Weiglton8t RotaiySi-d; Flow Rate.

P tnable Orialieacr'

ft·lll

ke> rpm IP"

r ~·-

SteemQ Tool Onent.

10.00

Oril lnteivat Record Interval:

l:m o lllo

8~ Coelficier.t

150

Formaoon Hardne$$:

130

Rate of Penettlllion.

1300

I~

' + Up/A~ · Oown/Lelt

:si ro

'Weblte Str"!I

'52.23

Tilt

!063

Force

1·1493

ti

Orecllon Welbole

122505

Stnno

[22511.i

It

Til

ft

Force

1000 jo

lb/

Build Role

1·2.00

·11cn1

Wiii\ Rate

/0.07

·11cn1

N&es

ft/hr

- o~ l bi not pretenl" the $1J11g

.,

~ Oiiabled for ec~nc components

WeigltOnB~

OK

Cancel

a. The build rate is -2.8 degrees/IOOft. b. The walk rate is 0.07 degrees/lOOft.

3-106

-@!Bl



I _i:_~ J


Determine Where BHA Contacts the Wei/bore 94.

-LEO ENO

- ow-~anee

20000

20050

g

20100

~ Q)

a

¥ 20150 ::>

"' Cl) Cl)

~

20200

20250

20300

·200

· 1 50

·1 00

· O50

000

D1splacemen1 (ml

050

1 00

1 50

200

a. The BHA is in contact with the wellbore when the Clearance line is at 0 displaceme nt. ln this example, the stabilizers are all in contact. Moving up the string, the coll ars are also in contac t. Further up, the drill pipe is also in contact. b. The inclination curve indicates the BHA displacement is in the inclination plane. Refer to the online help for more information.



3-107


95.

LEGEND Side Force

20000

20050

g

20100

~ Q) 0

~ 20150 ::>

lG

Q)

:E 20200

20250

20300

2000

4000

6000

8000

10000

12000

14000

Side Force (lbf)

16000

18000

20000

22000

24000

a. The greatest side forces are located at the contact points you saw on the previous plot. b. The first stabilizer has the highest side force.

Evaluate Effect of WOB and ROP 96. Select BHA Parametric from the Mode pull -down list.

3- 108

WEL LPLAN™ Software Release 5000. 1. 10 Training Manual



97. Using Parameter > Analysis, specify the fo llowing WOB and ROP data. ~

IP BHAParametric Orill11 he11d

Parameters

l21XX11i jooo

A-Ill

Steemg Tool Onent Rotary Speed

1120

rpm

Flow Rate

j6150

gpm

Dr• lnle
Imo

It

Record lnlervel

1~0

fl

B• Coefocient

lso

f Of!Mbon Haidheu

l:.i

TOlquelll Bt

~ l;;nablo Or~4<1

ROP lllhr

so 25.0 35.0

150 35-0 500

r~

OK

WEL LPLAN™ Software Release 5000. 1. 10 Training Manual


C.n:el

H.-,

3 -109


a. Use View> Plot> Weight on Bit to determine how the build rate is affected by weight on bit. After 26 kips WOB, additional WOB does not have much effect on the build rate. There is not much change in walk after this point, either. At some point, the string settles into an equilibrium state and is less sensitive to WOB changes.

LEGEND

-

-

\l',()6vs!luld

\11,()6,,,,Wolk

1 00

0.50

8 0

~

;Qi"·0.50 -t-ir------t--:::~~-+-~·-~-'-~'-'.+~~.......~..._-+--.........-+--....._+---4- ................+----"+---4

a;

a::

'O

5

Cl'.l.1.00

·1.50

· 200

6

3-110

10

12

14

16

18

20

22

24

Weight on Bit (kip)

26

28

30

32

34

WELLPLANTM Software Release 5000.1.10 Training Manual


36


Using Stuck Point Analysis (Using Stuck Pipe Module) Input General Analysis Parameters

I

98. Activate the Stuck Pipe module using the JJt toolbar icon and select Stuck Point Analysis from the Mode pull-down list. 99. Use Case> Stuck Pipe Setup to input analysis parameters.

[1)(8)

,,,. Stuck Pipe Setup Data Hook.\.oad/11./ei!tll·lrdcala Correction

jso.o

lravelng Assemiljy W'!fll#.

r

krp

f.nable S~ Fnctlon Correction

l.ne: S~ung MechMcal Elfciency(si'9e she<'lvet

%

Mechanical Lml<'!IJOlls

~ MlllCll1Un Slllface Taque

j750.o jmno

W

1~00

r,;Rio~

Maxinun tlveip
o"



C<'lnoel

krp

fl·lll %

Hejp

3- 111


Determine the Stuck Point 100.Using P ar ameter > Ana lysis, specify the initial load of the stretch test was 345 kips, and the final load was 365 kips. The stretch was 23.8 inches.

Opera(i'lg Mode BelOle Stuck Weight DnB~

kip

Measured Weight When Stuck 1405 0 Stuck Point Depth r. Compute Stuck Point Depth of Stuck Point

kip

r

Initial Hookload

j345.0

kip

FNI Hookload

j365.0

kip

Stretch

j23.800

n

MD ol Stuck Point

I

ft

Jar Position

a. The measured weight when stuck is 405 kips. t

·Stud Por11

:r.

Operotng Modo Before Stucl. We.ghl OnB•

ITril)plllg Out 22 3

Me8•..ed Wei!t
3 kip l<.ip

r

11111181 Hool'lo-'
j3450 j365o l23eoo

MD ol Stuck Por.t Jat POSfJOn

kip kip

., It

~lud'Porit

b. The stuck point is at I 9,227 ft MD. c. Yes, the stuc k point is below the jar.

3-112




Setting and Tripping the Jar 101.Use the Mode pull-down list to select the Jar Analysis mode. 102.Use the String Jar Data dialog box to specify the jar operating parameters. To access the String Jar Data dialog box, double-click a non-editable field associated with the jar on the Case > String

Editor. 'P1 String .Jar Oata Fromcaaog.

-

-

-

CTJ(g]

-

J

Gonetal Desci!Pbon lMechri:41 J.v Daie)i Mech.. 61 /4 in

~

Mwact1.1e1

Twe

3

l Meclwlic
t.ne..~

lo.oocs

bbl/ft bbl/ft

ao-l End Oisplacemert

fU0380

Length

130.00

fl

Makeup TOlque

j21soo.o

ft·lbl

BoqyOD

(6.250

n

..

Mirwrun Yield Stre119'n

1110000.0

psi

Coll
wl

YOl.l'lg'sMoW!ui

l:mmxi.oo

Poouon's Ratio

lo.JOO

Dem«y

l400

Model No.

BoqylD

12.250

Appi00
fnea

Grade

l 4145HMOO

Malet.al

l cs_API

Connection

I• 1121F

~ ~

son

psi psi

bnlft'

f-06/'F

Coelf of Th«mlll E1CP

"'

Up Set FOlce

110.0

Down Set Force

fa.a ls.a

Punp Open Force

k4'

Up T'4' Force

110.0

k4'

Down T~ Force

fma

~

Seal Friction F01ce

ls.o

OK

I

Cancel

k4' k4' k4' Ai:q.

H~

103.Use Parameter> Analysis to determine the forces to set, trip, and reset the jar. I~

Outpi,t

Opeiatng Mode Before Stuck

IT rWiog Out

Wetrj:i On Bi

j12.0

t:J krp

MeaSlled Weil;# When Stuck .--j405--.0 - - - k~ Stuck Pm Depth

r.

Jar Opet~ Force Jar Set Force

1100

k~

Jar Trrp Force

jmo

krp

Jar Opeietong MeaslMed W~

Compute Stuck Pont

IMal Hoddoad

j345.0

Final Hookload

j365.0

Slletch

j21aoo

r. Jars Up (" Jen Down

Set OntialJ

Ima

krp

Trrp

l4c.> 4 13864

krp

1·161 2 1162.7

krp

1-200

Resd

Bucking Mode

1-

11-

Buckling Modes: ~·"No Buckling. 'S'• Srosoidal, 'T' • Translboo. 'H' • Heflc~I. l' •lockup

MD ol Stuck Point Jar POSlllOl'I

Owige

Meas1Med Weight

(" Depth ol Stuck Point

jAbOVe Stuck Poot r. P1.WTIPS On (" PlMllP$ Off



3-113


Yielding the Pipe 104.Use the Mode pull-down list to select the Yield Analysis mode . I 05.Use Parameter> Analysis to determine if the loads required to set, trip, and reset the jar cause the string to fail. The pipe does not yield or buckle using the loads required to set, trip, or reset the jar. If you slack off enough, the string will buckle (sinusoidal). l...,U Opeootno Mode 8elcl• Sluek

l•@ll!

W~OnBi

112.0

M...,..edWeo#WhMSlld 1405.0 Stud< Pooni Oooth

::J

loo

ko

Rold
kc>

lnobal Slbh.l> OI Stuck PQr>l

C: ~· Sluck Pon

r

O\lpl.i ll'lhol Status al S..tace

Oe¢1 ol Stuck Pcr.t

lttl

F01Co n Oril Sling (PAI

1·131'

k4>

FClcenOriSlmg [BUOY)

jo.7

kc>

ll'lholHool
13450

10.0

fo

j365o

I.JP k4>

F0tca a1 the Si.ck Pan

F.,., Hool
I orque at the Stud< Pon

loo

lttil

Sb etch

fZl.800

n

M,_... Ov...... to Lood Stud<. Pon

lol{li4 lo•

MO of Stuck Pon

M-..odYle9'1

J•PApplied Load Me-..edWat;f'l.J

Ov"'l>UI (+I

M.......,

1200.0

M_,..,,

1500.o

.,.,ko

Mnmun Sladoll to Lood Stuck Pan

lnaement

1100

ko

Aj)l)loodM04Med

M_....Rol•y

WO'Kj'A

Torque

P<.,I

(tt-till 871566 86967 5 9G765 7 9G9.i1 2 96l23 8 8600'.3 5

858301 85563 7 852839 81!l'Jl7 846839 81363' 8'0291 836ll07 B.3J18, 82$111 ~96

ko

kc>

M........tW~

j2605

•.op

Slackoll l·l

1·144.S

ko

OvOlfl'A'•V Slad)

-2050 ·1950 ·1850 1750 -1650 1550 l•SO 1350 ·1250 ·1150 -1050 950 ·8'50 ·750 650 -550 450 ·350 -250 ·150 50

Section OP DP DP DP DP DP DP DP DP DP DP DP

YooldPan M-..ed OOl)lh I

Slucl
s s

no

DP DP

00

OP

~)

00 00 00 00 00 00 00 00 00 00 00 00 0.0 00 00

DP DP

Force nOril Pie.MoAt04

Backing Off 106.Use the Mode pull-down list to select the Backoff Analysis mode.

3-114




I 07. Use Parameter> A na lysis to determine the surface actions required to back off at 19, 158 ft. Input

3

OperaM!I Mode B!!IOfe Stuck 'Wf!iti#,On Bt

qi

1120

qi

Measued Well# \I/hen Slid l.oo 0

Stud Point Depth r. ~e Stuck Pon r Deplh of Stuck Point Initial Hookload

1345 0

~

Fnlll Hook.load

13650

kip

Stretch

l23EOO

MD of Stuck Pont J111Podl0rl

Backoff ~SIS MD Fu Backoff

BelOfe Stuck 14ffi 0

~

Rotaiy Tllille Tuque

loo

It-Ill

loo

FOfce Al BackOll MD (PAJ

l·12S.O

kip

l·12SO

FOfce Al Backoff MD (BUOY) 12. 7

kip

12 7

TOlque At Backoff MD

ftb'

loo

Meaued\llfit;l1.

loo

.,

lnlbal Surface ActJoo fOf Set Up Measured \IIeigtll

j264 2

ft

M111llU111 ll'lllial Oveipul (• ve) I Stackolf (·ve)

l·UOB

jAbOVe Stuck Pori 119158 0

Output Condiliona Priol to Backoll

Fml Surf<\lte Action Fu Backoff

kCi

M~ed Wei/Tl.

14~5

kCi

It

Rotaiy Tllille Tuque

1200>0

lt·b'

Ove1pul (•ve) I Sklckolf (·ve) from Set Up MMsuredWfit;l1. l142 3

Backolf Fuce

l5 o

kCi

Backolf TOfQUe

1200> 0

lt-b'

kCi

a. The ini tial s urface action is to slack off 140.8 kips. b. Slacking off releases the tension in the s tring.

c . To back off, pic k up 142.3 kips.



3-115


3-116



Chapter.

Running Liner Overview Data The data used in this exercise is not from an actual well. Although an attempt has been made to use realistic d ata in the exercise, the intent when creating the data et is to displ ay software functio nality. Therefore, some data may not be realistic . Please do not let the accuracy o f the data divert attention from acquiring knowledge of software functionality.

Workflow In this section, you will analyze running a liner in the wellbore section drilled in the last workfl ow. Determining centrali zer pl acement is the first step in the workflow. Both ri gid and bow centralizers are used in the analysis . Comparison of the hookloads with and without centralizers is pe1formed. Initially, a highlevel torque drag analys is is performed. A more in-depth torque drag analysis while tripping and rotating on bottom is performed. Actual load data is used to val idate the selection of cased and open hole friction factors. The S urge module is used to analyze the transient pressure (EMW) responses while running and reciprocating the liner. Mud temperature effects are examined. Conventional and autofill fl oat options are investigated. A tripping schedule is generated to determine maximum trip speeds possible without exceeding the fracture gradient. The fi nal step in the worktlow involves conditioning the well prior to cementing.



4 -1

Chapter 4: Running Liner

Workflow Solution Solutions for the workflow steps in this chapter can be found in the Running Liner Solution chapter.

What Is Covered During this workflow you will: • • • • •

4-2

consider effects of both conventional and autofi II fioat shoes. analyze surge and swab transient pressures at several depths. review the effect of centralizers on ECO. review the effect of tool joints on ECO. analyze reciprocating the liner.




Input and Review Well Configuration and Analysis Options I. Using the Well Explorer, open the Case titled "Running Liner. "

2. Review the casing string. What is the liner overlap? 3. Ensure the mud weight is 13.8 ppg. TM

Because of the integration between the W ELLPLAN software modules, the wellbore data from the Drilling case is available to the Running Liner case.



4-3

) Chapter 4: Running Liner

Centralizer Placement (Using OptiCem ™ Module) 4. Activate the OptiCem-Cementing module. 5. Activate the Centralizer Placement analysis mode. Use the Centralizer Placement mode to calculate either the standoff yielded for a required spacing between centralizers or the spacing between centralizers needed to achieve a required standoff.

Using Bow Centralizers 6. Import the Training Centralizer catalog and Training Casing Shoe catalog. 7. Select the Bow Centralizer in the catalog you imported. Determine the centralizer placement using the following parameters. •

Calculate centralizer placement based on standoff.

•

The top of the centralized interval is 15,000 ft.

•

Assume the cement design requires 70% standoff in centralized interval, and 40% above the centralized interval.

•

The maximum distance between the central izers is 160 ft, and the minimum distance is 20 ft.

•

The calculated step size is 500 ft.

•

The trip speed is 60 ft/min, at 0 rpm. CAUTION In order to update results in the Quick Look section, you must click Copy to Standoff Devices on the Parameter > Centralizer Placement view. Therefore, if you change any data, click this button to update the results . If not, the results calculated using standoff devices may not be accurate.

a. What is the hookload with centralizers? b. What is the hookload without centralizers?

4-4



Chapter 4 : Running Liner

c. What is the maximum hookload and where does it occur? 8. How many bow centralizers are required? 9. View a graphical representation of the hookload with and without centralizers using the Torque Drag Analysis plot. Why is there less hookload with centralizers? 10. Freeze the curve representing the Hookload with Bow Centralizer.In a future step, you will compare the Hookload with Bow Centralizers to the Hookload with a Rigid Centralizer.

Using Rigid Centralizers 11. Replace the bow centralizer with the rigid centralizer from the Training Centralizer catalog. Hint Use a tab other than the tab displaying the Torque Drag Analysis plot.

Note If you use the same tab to display another plot or view (for example, the

Parameter> Centralizer Placement view) that you use to display the Torque Drag Analysis plot, any frozen lines will be lost.

12. Use the same analysis parameters that you did for the bow centralizer. What is the maximum hookload and where does it occur?

13. Review the Torque Drag Analysis plot using the rigid centralizers. How does it compare to the torque drag using bow centralizers? 14. How many rigid centralizers are required? Use the same tab you used to view the Torque Drag plot.



4 -5


In-depth Torque Drag Analysis (Using Torque Drag Module) Using OptiCemTM, you performed a high-level torque drag analysis. Now you can use the Torque Drag Analysis module for more in-depth analyses of additio nal operating modes. 15. Activate the Torque Drag Analysis module. 16. Access the Drag Charts analysis mode. 17. Input the following analysis parameters. •

Analyze every 500 ft between 0 and 20,000 ft.

•

Analyze tripping in and out at 60 ft/m in. There is no rotation.

•

Analyze rotating off bottom in addition to the two tripping operations.

18. Review the hook loads for each operation with and without centralizers. Are the loads within the yield limi t and rig capacity, with and without centralizers, when tripping out? Hints Use the Freeze line. Use the Standoff Devices dialog box to indicate when you want the centralizers used in the plot results.

Note If View> Auto Calculation is checked any time there is an OptiCem view or a plot open in a tab, the calculations will be performed. This is typically not desired when using another WELLPLAN module. Therefore, if you have an OptiCem view active in a tab, you may want to consider replacing it with the plot required for this step.

19. Include centralizers in the analysis again before proceeding.

4-6




Matching Friction Factors to Actual Field Data 20. Analyze tripping in at 60 ft/min and 0 rpm every 500 ft between 10,000 and 20,000 ft. 2 1. Enable the sensitivity plot. 22. Input the following friction factors for sensitivity analysis. Casing

Open Hole

Min

0.0

0. 1

Increment

0.2

0.2

Max

0.4

0.5

23. Specify the follow ing actual load data. Run Depth (ft)

Trip In Measured Weight (kips)

10,000

3 13

12,500

293

15,000

271

17,500

276

20,000

284

24. What friction factors are you currently using? 25. Do the friction factors in use (from Case> Hole Section Editor) match actual load data? 26. Is the make-up torque li mit exceeded if you rotate while tripping in the liner? Analyze it at I 0, 15, and 22 rpm.

WELLPLAN ™ Software Release 5000.1 .10 Training Manual


4 -7


Determining Surge and Swab Pressures (Using Surge Module) Input and Review Well Configuration and Analysis Options 27. Access the Surge module application. 28. Review the string data. a. Review the casing shoe information. b. What is the difference between conventional and autofill ? c. Select the conventional float opti on. d. What module uses the fl oat opti on? 29. Review the standoff devices.

Specify the Operation Data 30. Specify the following operation data: •

Analyze a surge operation.

•

Include mud temperature effects.

•

Pipe accelerati on and deceleration is I ft/sec 2 .

•

Specify the followi ng moving pipe depths and corresponding pipe s peeds: Pipe Depth (MD)

4-8

Pipe Speed (ft/min)

12500

155

15,000

155

19,9 10

155




a. Why sho uld you analyze 15,000 ft MD as an additional depth of interest? b. What is the length of a stand of pipe?

c. Why is the deepest pipe depth not at TD?

Analyze Transient Response 3 1. Review the transient EMW, at all moving pipe depths, as a function of time. a. Is the formation fractur ing at any depth? b. Using the Transient Response plot at TD, freeze the curves that

are fracturing. Change the names of the curves to indicate a conventional float is used. 32. Does auto-fill help reso lve the problem? (Use a different tab to access the String Editor.) a. Is there still the possibility of exceeding the fracture gradient at TD? b. What is the EMW reduction at TD when the moving pipe depth is at TD?

c. ls there still the possibility of exceeding the fracture gradient at the shoe? d. Is there still the possibi lity of exceeding the fracture gradie nt at 15,000 ft MD?



4-9


Check the Tripping Schedule 33. How can you reduce the ri sk of fracturing the formation by altering the trip speed?

a. What is the trip speed at TD, at the shoe, and at the depth of interest? b. What speeds should you trip if the auto-fill becomes plugged? Compare the auto-fill resu lts with the conventional results. c. Enable auto-fill before proceeding. 34. Recheck the transient pressure responses to determine if there is an issue using the s uggested trip s peeds. Use 125, 120, and 115 ft/min for 12,500, 15,000, and 19,910 ft , respectively.

Reciprocating 35. Select the Reciprocation analysis mode.

36. Specify the following analysis parameters: • • • • •

Reciprocation depth 25 ft above TD ( 19975 ft) Reciprocation length 22 ft Pipe acceleration and deceleration is 0.5 ft/sec 2 No additional depth of interest 0 gpm flow rate

37. Are there any transient pressure issues at TD? 38. What flow rate resolves this issue?

4-10




Condition the Well Prior to Cementing (Using Hydraulics Module) 39. Access the Hydraulics module. 40. Access the Pressure: Pump Rate Fixed analysis mode. 4 1. Do not use central izers in the analysis. 42. Determine how long it takes to circu late two circulations using a pump rate of 400 gpm. 43. Specify the analysis parameters. Don't include tool joints in the analysis, but do include mud temperature effects . Analyze every 500 ft between 12,500 ft and TD. C irculate for eight hours. 44. Review the ECDs as a function of depth. Freeze the ECO curve on the plot using Freeze Line. 45. Do tool joint pressure losses alter the results? If so, why? Freeze this ECD curve also on the plot using Freeze Line. 46. Include the centralizers. Is there a change in ECO? Why is the ECO increased after 15,000 ft MD? 47. What is the circul ating temperature at TD, and what is the return temperature at the surface?



4- 11


4-12

WELLPLANTM Software Release 5000.1. 10 Training Manual 恭贺新禧! http://www.egpet.net ‫ﺷﻛرا ﻟك‬

Chapter

II

Running Liner Solution Overview This chapter contains the answers to the exercise questions presented in the Running Liner chapter.



5 -1

Chapter 5: Running Liner Solution

Input and Review Well Configuration and Analysis Options l. Double-click the case name in the Well Explorer to open the case titled "Running Liner." 2. Access the Case > String Editor. The liner overlap is 250 ft. (Previous casing shoe is at 12,500 ft.) Stmgln1J41zall0n SknoNomo ~ ~ --------------

St~ (MDl

l2aXXl 0

SQto8ctton1

:::J

l~Stmg~

Meb>Uod

1225000 6.00

m2.oo

2.00

E>qlOfl

1""""1

OD

o:in

SecbOO ll'P"

u...,

ID rnl

lnl

12250.0 122560 199980 200ll0

5.000 12000 9625

9625

HOO

2935

8535 8535 8535

53 50 l.roer Hanger 5350s5l8 ... 5lspp1.o-125. 1..,..,.a1ue 51511 lraonrigS6251'l.5l5ppl. Q-125

D~~S..,,25.60ppl . S. 5112FH . 1

3. Ensure the mud weight is 13.8 ppg using Case> Fluid Editor.

f'g)

IP Fluid Editor PP9

113.80

•t

5

El E}

IBhj1am Plastic

Rheology Model

!3.8PPQ06M 14.0ppg Spacer 14.5 PP9 Lead 16. 4 PP9 Tail

RheoloQy Data

jFann Data

Temperatu-e Plasb: Viscosity

j10.00 j 20.00

cp

Yield Port

ra.oro--

li/11X1t2

Of

ALid Plot

Fam Data

Save RPMs as Default Speed

(rpm) 600

300

0

800

1000

Shur fbt t (11sec)

__I_

~°"

5 -2

Cancel

J____.



I

Dial (")

48.00 28.00


Centralizer Placement (Using OptiCem TM Module) 4. Click the

0

toolbar icon to activate the OptiCem module.

5. Activate the Centralizer Placement analysis mode using the Mode pull-down list.

Using Bow Centralizers 6. To import the catalog, right-click the Catalogs node in the Well Explorer and select Import Catalog from the 1ight-click menu. Using the Import Catalog dialog box, navigate to the folder containing the catalog file you want to import. Be sure the File s of type: pull-down list says "Catalog Transfer Files (*.cat.xml)." Notice the Well Explorer now lists a catalog titled "Training Centralizer." Repeat this procedure for the casing shoe catalog.

·_ .......

..,,._ ... ~"

,

- •Catalogs - !W Drilling Tools + Accelerators + Adjustable Near Bit Reamers

g mJ

+

~Bits

+ ~ Casing Scrapers

m m m -m m m

Casing Shoes Casing/Tubing Connectors + Casings/Tubings Centrafizers Halliburton Tra1n1ng Centrahzer + ~ Coiled Tubings + (gt Core Barrels + +

• Im r 1.~~!nnc R1>M Tmn <>R1>rc



5-3


7. Use the Parameter> Centralizer Placement view. Click on the Centralizer A cell, and select Use Catalog Selector from the pulldown list. The Centrali zer Specification dialog box will be displayed. Use this dialog box to select the Training Centralizer catalog from the Catalog pull-down list. Select the bow centralizer.

1p1

Cent;alizer Specification

Catalog:

-

JTraining Centraizer

Casing Diameter

l1JL'8J

_ Reset_J Hole Diameter

Nominal Size

OK Cancel Help

5-4



)


Input the provided running parameters using the Parameter>

Centralizer Placement view. r.

Calculate S1andoft/Spac1ng _ __

(" Entered Slan•

0

FIUtd Profile

%

(" As Top Plug Lands

P" Top of Centraltzed Interval

I

j1soooo a MO Spacing l.JITl11s (Between Centralaers) Maximum Distance

(i Ounng Mud CondlllOmng

Staodolf Above Top 40 00

iJ

WeRbore Fluid ~-------O'"' ' "" rpg

j•

j160 0

Minimum Distance

!20 0

ft

Imo

MudOensll)'

ppg

Specify the intervals s1arlHlQ from lhe swface down to TO (lhe opposite order l1om wtuch they ere ran into the hole) Torque Drag Analys1S (Casing Running in)

I

Copy to Standoff Devices

Cale Step Sae

I

!soooo RPM

Speed

r

Tnpptng Ill

LEGEND

r-

ft.Iman

g

r - ipm

£a.

Quick look

"'

0

Stabc Hookload at TD With Stando" OeVlCes Included

125" 3

Excluded

-, 306 - 0 - - kip

"Cl 10000

.,.e

:J

kip

(0

"'

~

ioo- 11-lbl Min Hooldoad isoo- kip

@MO

ioo-ft roe-ft

Ma~ Hooldoad j294 9

@MO

feoooo

Max Torque

kip

@MD

5000

15000

a 45

50

55

60

65

10

Standoff (%)

a. Click Copy to Standoff Devices on the Centralizer Placement dialog box to update the Quick Look results. The Hookload with Centralizer is 254.3 kip. b. The Hookload without Centralizer is 306 kip. c. The Max. Hoakload is 294.9 kip@ MD 8000 ft. Note The values in A 7a, A7b and A 7c changes with later versions of R5000. I.9 and R5000. I. I 0.



5-5


8. Use Parameter> Standoff Devices to determine how many centralizers are required. In this example, I09 centralizers are required. "

I

v Use S1.!lndoff Oevces

Selocl From Caiblog

I

Cqiy from Cenlr"'- Placement

Relabve Fncbon SIMI ~

36211 l>673 37135 37598

:mso 38523 38986 39448 39911 4037.5 40838 41~1

41164 42228 42692 43155 43619 4~ 3

4454 7 45012 45476 4594.0 46405 46869 4733 4 4779.9 4826 4 4872.9 49195 49660

End tt 36673 3n35 37598 38000 38523 38986 39-44 8 39911 40375 40838 41~1

417&4 4222.8 4269 2 43155 4361 9 «0!3 4454 7 45012 45476 45940 4640.5 46869 47334 4n99 4826.4 4872.9 4919.5 49660

sano

01ag

000 000 000 000 000 000 000 000 000 000 000 000 000 000 000 0.00

Tacµo

noo

000 000 000 000 0.00 0.00 0.00 0.00 000 0.00 000 000 000 000 000 000 000

000 000 000 000 0.00 000 000 000 000 000 000 000 0.00

000 000 000 000 000 000 000 000 000 000 000 0.00

noo

I

l>JRl!)ld

I

OtJIOde O.....ieteo

.,

AdlM1'

13500 13500 13500 13 500 13500 13500 13.500 13500 ll500 13500 13500 13500 13500 13500 13500 13500 13500 13500 13500 13.500 13500 13500 13500 13500 13500 13500 13500 13500 13500 13500

NoR9d

I fOICe R.....-.g

Hole

Fr

Oiameieo

Elfecbve In 11 250 11250 11.250 11 250 11 250 11250 11 250 11 250 11 250 11 250 11 250 11 250 11 250 11 250 11250 11250 11 250 11 250 11 250 11 250 11.250 11250 11 2'50 11 250 11 250 11 250 11250 11 250 11250 11 250

fn) 12.250

Starting

(bl)

1151 0

C'

g

(I)

u .... 0

800

LL

600

0

>

<

5-6



50

Hole Diameter (m)


9. Use View> Plot> Torque Drag Analysis to view a graphical representation of the hookload with and without centralizers and compare with results using bow centralizers. There is less hookload with centralizers because there is more drag, and the drag force acts in the direction opposite of motion. LEGE ND

LEGEND

-eCentral::tiS - A "'°' WIMut CtidrdZe
~ Wtl> Cenlftlzer•

- • --- Yftt\out Cet*alzers

2000

•ooo 6000

g

8000

.c

~

..,

0

...

~ 10000 -

:E

cl"

12000

14000

16000

18000

20000

r i

T

so

100

150

200 Ho<>Jdoad (kip)

250

JOO

·3

·2

·1

0

2

3

Torque (ft·fbl)



5-7


l 0. To "freeze" a curve on a plot, click the curve, then right-click and

select Freeze Line. It is helpful to change the color, line thickness, and/or curve title to distingu ish the various curves. lEGEHO - - WillC-.1!.... - A - W0101A. CMtrlt::ttS

2000

4000

6000

e:

.

8000

"'a.. 0

-e

" i=

10000

§ a: 12000

1•000

16000

18000

20000 50

100

150

200

250

300

·5

4

Hooldo•d (lap)

.3

·2

.,

0

2

TOtq11• (l-ltll)

Using Rigid Centralizers 11. Use Parameter> Centralizer Placement. Click on the Centralizer A cell and select Use Catalog Selector from the pull-down list. T he Centralizer Specification dialog box will be displayed . Use this to select the TrainingCentralizer catalog from the Catalog pull-down list. Select the rigid centralizer.

5-8



Chapter 5 : Running Liner Solution

12. Remember to click Copy to Standoff Devices. The maximum hookload is 330 kjps and occurs at 8,000 ft. ...... F1.tt.._.

-

-

---------

- - -

~ Standoff/S-

•

r

Erl"'ed Standol!

..,

. . . . - - '-

F\ld Prof• As TOD P\JO IAndt

TOllolc.n.~lrltrVal

MO

(1SllXJO

S-~ TOD~~

a

• Oling Mud ConcllioMg WolJore FUd ... ,

-------3-.

Pattern

r r

A

r r

r r

70.00

Spocjylhe ro!e
''""'° Drao~fCamoRllWlrG"I (OD!ltoStandcltD...:esl

CC S•eo S...

isoocn- ft Speed

r

1"""'10 tn

--

RPM l'\/l'IW'I

Ci. Q)

r-"""

0 "'O

O<.d- Look S1.,icHoolJoad at TD ...ih Standolf 0"""•

lrd.dod E~

M.. T.. CJMO

~

~kip ln>J ~IP roo-11-1>1 @MD

Mf'Hooldoad [soo- ~IP IM., Hcdlood l:ms ~

@MD

C:t) Q)

~

[Oo-tt 00-- ft

@MO 80ll0

10000

:J

en

15()00

20000 40

50

55

80

65

70

Siandoff (%)

~



5-9

)


13. Click the tab that contains the View > Plot> Torque Drag Analysis to compare the hookload using bow and rigid centralizers.

,000

6000

s

.c

8000

a.

~ .,,

e

: i

10000

c

er "' 12000

14000

16000

18000

20000 50

5-10

100

150

200

250

300




14. Using the same tab you used to view the Torq ue Drag plot, access the Parameter > Standoff Devices to determine how many rigid centralizers are requ ired . Scroll to the botto m of the spreadsheet. There are 93 centralizers used. OeYOCet

- - - - - - - - - --

- -

WELLPLANTMSoftware Release 5000.1.10 Training Manual


5- 11


In-depth Torque Drag Analysis (Using Torque Drag Module) 15. Activate the Torque Drag Analysis module by clicking its toolbar icon (

**h·

16. Access the Drag Charts analysis mode using the Mode pulldown list.

5- 12



)


17. Use Parameter> Run Parameters.

ITJ(8]

,,; Run Parameters - Drag Chart Run Definitions Start MD:

Jo.o

ft

End MD:

120000.0

ft

Step Size:

1500.0

rt

r

ft

Torque/Tension Point Distance from Bit

DriUing

r r r ~

Toroue at B~

WOB/OverDUll Rotating On Bottom

kip

Srtde Drifing

kip

Backreaming

kip

r

fHbf

I I

ft-lbf fHbf

Rotating Off Bottom

Tripping Speed ~

Tripping In

P

Tripping 0 ut

lso.o fso.o

RPM ft/min ft/min

lo lo

rpm rpm

Friction Factors Casing

r r

Calibrated

r

User

I

r.

Hole Section Ed~or

r

Advanced

Open Hole

Advanced

Friction Factors ·Sens~ivity

r

Enable Sensitiv~y Plot OK



Cancel

I_ Apply

Help

5-13


18. Display View > Plot > Tension Point/Hookload Chart. Use Freeze Line to ensure that the curves for running with centralizers remain intact so you can compare the resu lts to those without centralizers. (To access Freeze Line fun ctionality, rightclick the curve, select Freeze Line, and change the properties us ing the displayed dialog box.) or~ Drag Hool

Lo!ld Chari

Hook Load (kip) 100

200

300

400

500

600

700

800

900

1000 1100 1200 1300 1400 1500 1600 1700 1800

0 2000 4000 6000

g

t

Q)

0 c

8000 10000

;;;)

er

12000 14000 16000 18000 20000

5-14




In another tab, access Parameter > Standoff Devices to indicate centralizers should not be used in the analysis. Uncheck the Use Standoff Devices check box on the Standoff Devices spreadsheet. 516'ldcllf D~e'

~- __ _ _ _

WELLPLAN ™ Software Release 5000. 1. 10 Training Manual


_

_

__

_ __

5-15


Access the tab with the plot again. Notice that the results without central izers are now displayed on the Tension Point/Hookload Chart along with the results using centralizers. Notice that all loads for all operations are within the yield limit of the pipe. This plot can also be used to compare the rig capacity to expected loads. In this particular case, there is a 100-kip difference between the expected tripping out with centralizers load and the rig capacity.

100

200

300

400

Hook Load (kip) 500

800

700

800

900

1000 1100 1200 1300 1400 1500 1600 1700

1800

0

2000

LEGEND Trippfna OU - wlh certroli?ers O Rciiiie "Ott Bollom - wih certrali%ers Tt1pplng In - wlh centrai:z.ers o Rotate Ott Bollom ~ T!Wing OU " T~ln --J- M(IX Weigt1 Yield (T~ OU) - 8 - Mi'l W . Het Buclde (Tris>l*>g In) ~

4000

6000

g

8000

£

c3a. 10000 c:

:l

er

12000

14000

16000

18000

20000

Note A s you cursor over a curve with the mouse, notice the curve turns black. The cur ve label in the legend also turns black. This can be helpful when determining what the curve represents, particularly when there are several curves on the plot with the same, or close to the same, color.

5-16




19. Access Parameter > Standoff Devices and check the Use Standoff Devices check box on the Standoff Devices spreadsheet. ~lando_jf (lew:ei

- -- - -- - -- -

Select From Yleloo Oetarce lrotn TO 51411 ft

F7 F7 F7

p p p p p p p

IV IV IV IV F7 F7 F7 F7

"' r;; p

,.. p

r;;'

F7

p F7 r::;

p

"'"'

3J165 3371 2 J.426 0 :W09 35357

35!n6 36455 37005 37555 38105 38656 39207 3975.8 '°31 0 40861 4141 4 41966 42'51 9 4:ll7 2 43626 44180 4473.4 4528 9 4584 3 46398 4695 4 4751 0 466 4862.2 49179 49736

Copyfrom cema1inv PlacemerA

-

Erd (ft}

33n 2 J.426 0 34819 3535 7 35906 36455 37005 37555 3111Q5 306S6 39207 397'5.8 4031_0 .oeG 1 4141 4 41 966 4251 9 43)7 2 4362.6 44180 44714 4528.9 4584.3 4639_8

"695 4 4751 0 41" 6 48622 4917 9 49736 SOXl O

Aelal:Ne Fnc110n Drag

150 1.50 150 150 1_50 1 50 1.50 1 50 1.!ll 1 50 1 50 150 150 1 50 1.50 150 1 50 150 1 50 1.50 1 50 1-50 1 50 1.50 1.50 150 1 50 1 50 150 150 150

Tor1 50 150 150 1 50 1 50 1.50 1 50 1 50 1 50 1 50 1 50 1 50 1 so 1 50 1 50 1 50 150 1 50 1 50 1.50 1 50 1-50 1.50 1 50 1 50 1 50 1 50 1 50 1 50 1 50 1 50

I

Al Rigid

Ot.tSllle 0-or

NoAigod

J

Fr

H<>ie o-or

AClu.ll

EfleclMl l"I fl"I) 1200) 12001 1200) 12(XXJ 1200> mm 12000 1200> 1200) 12Jl00 1200) 12.00l 12 000 12.00l 12 CXXl 12.00J 12 CXXl 12 CXXl 1200) 12-DXl 12.00J 12.000 12.00l 1200> 1200> 12.00l 1200) 1200l 12.00J 1200l 12.00l 1200l 12.00l 1200> 1200) 1200l 12 00) 12000 1200l 12.00l 12-(XXJ 12.00J 1200l 12.00l 1200) 12.00J 12.00J 12.00J 12.000 12.00J 12.00J 12.00J 12 00> 12.00l 12.00l 12.lm 12 00J 12.lm 12.00l 12.lm 12.00J 121m

r (

I

(n)

Force Statr.g Aurvwig (Ill)

00

12250

-0

<>

c

00

LEOENO Siering Fotce R\nil"lg Fotce

20

.0

c

(I)

~

0

0

LI.. · 20

· 40

0

50

Hole Diameter (in)



5- 17

Chap ter 5: Running Liner Solution

Matching Friction Factors to Actual Field Data 20. Use Parameters> Run Parameters. tl,i:J Run Parameters - Drag Chart Run Definitions Start MD:

110000.0

ft

End MD:

120000.0

ft

Step Size.

lsoo.o

ft

I

T orque/Tensron Point Distance from Bit

12000000

ft

Drilling Torque at Bit

WOB/ Overpull I

Rotating On Bottom

I

SlideDnlling

I

Backreaming

I

Rotabng Off Bottom

!2s o !2so !1sc

kip

I- ()(' o

ft·lbf

kip

120000

ft·lbf

kip

!1sooo

11-lbf

Tnppmg Speed

Iv

Tnpping In

I

Tripping Out

RPM

160.0 1600

ft/min

lo

rpm

ft/min

lo

rpm

Fricbon Factors

r.

Hole Section Editor

("' Advanced Fnction Factors -Sensrbvity I

Enable Sensrtivrty Plot

OK

5-18



I

Chapter 5 : Running Liner Solution

2 1. Check the Enable Sensitivity Plot check box on the Run

Parameters dialog box.

OK



5-19


22. Click Input Friction Factors on the Run Parameter dialog box to access the Sensitivity Plot Friction Factors dialog box.

r1]['8]

1P Sensitivity Plot friction fclCtors Fncbon Factors

Casino

Open Hole

Minnun

!IJ.OO

jo.10

Iner~

jo.20 j0.40

10.20 jo.50

Mm
Notes. Fist 12 inciemenl !lies wil show up on the sem«ivity plot

~

OK

H~

23. Use Parameter> Actual Loads to input the actual load data. ~ctual

Loads

_

________

Run Depth

Tr\? In

(ft)

2 3

__ _ 4

5 6

......

k"

10000.0 12500.0 l 5000.01 17500.01 20000.0 - - -

313.0 293.0"' 271.0 276.0 284.0

24. Use Case > Hole Section Editor to determine the friction factors you are currently using. You are using 0.2 in cased sections, and 0.3 in open hole sections. H~ S~tion Edoloi

!Hole Section

Hole Section Depth (MDt.

121m1.o

Secbon T_vpe

Meau.red Depth

fb--- R-

~ CMng

~O~ Hole

ti--

5-20

-

- -

Hole Name:

lfl)

590.0 12500.0 200Xl.O

Import Hole Section

p Addibonal CoUnns

ft

Shoe Length ffl)

lllpefed?

Depth

1![

590.oo r 11sio.oo r 750000

Me&SIXed

r

12500,0

Effective

ID

Dtift

Hae

fin)

(ii}

Diamelei

l'ncbon Fecioi

(in]

18.too 12.375 12.250

12.250

17.500 12.250

0.20 0.20 0.30

L~

Capacity (bbl/ft)

0.31 47 0.1489

0.1458

Excess (7.)

RSA Section, 20 in x 18 ii CAS 13 5/8 i1.. 88 2 ppi. O· 0.00 OH 12 1/2 in

r



Item De:oip(ion


25. Use View> Plot> Sensitivity Plot-Tension/Hook Load Chart to determine if the friction factors in use (from the Case> Hole Section Editor) match actual load data . Note that the actual load data points fall along the curve corresponding to a 0.2 friction factor in cased hole and 0.3 in open hole. These are the values you are using in the Hole Section Editor. ffi~yF1oHlw

Load(lr<;ll)l'lglnJ

L EG EN D -G- CAS FF• 0 00. OH FF • 0 10

0- CAS FF • 0 .20. OH FF • 0.10

~ CAS FF • 0-40. OH FF • 0.10

_,. CAS FF • - - CAS FF • ~ CAS FF • ~ CAS Ff • -W- CAS FF • 0 CAS FF •

+<>

0.00, OH FF • 0.20, OH FF • o.~o. OH ff . 0.00, OH FF • O 20, 0H FF • 0.40, OH FF •

400

030 030 0.30 0.50 050

050

:,x~~TCT~~?

Ac!Ulll TrippS>g In

13000

g

14000

5a_

i3

15000

-

c:

::l

a::

16000

17000

~

18000

19000

20000



5-21


26. Use Parameter > Run Parameters to specify the rpm, and use View > Plot > Torque Point/Surface Chart. When rotating at 22 rpm, make-up torque limit is exceeded. (11!11J i or~ PW Chari

11000 12000 ~

s

1l000

£

ata

1'000

"O

~ 15000

lll (l)

2 16000 c: ;;;i

0:: 17000

18000

19000 20000

5-22




Determining Surge and Swab Pressures (Using Surge Module) Input and Review Well Configuration and Analysis Options 27. Access Surge analysis by clicking the

Ua, J toolbar icon.

28. Use Case> String Editor to review the string data. 111n9Edtlor Stmg lnibanabon

_ _

_

Li:>rory

StriigNanWJ ..-ujA e~ -------------Sbl"l!I (MO~

] 200l0.0

rt

S.Qedy

ITop lo Bottom

:J

lmpo
Measured Depth

(ft)

Ori Pipe Camg Camg CamgShoe

12250.00 6.00 7742.00 2.00

I

E>
00

10

(1"1)

(n)

12250.0 12256.0 199SS.O

5.000 12.000 S.625 9.625

2!lm.O

Item Description

4.000 8.535

29.35 Orll Pipe 5 in. 25 60 pl)/, S. 5 112 FH, l 53.50 LM Hanger

8.535 8.535

53.50 S518n. 53.5pl)/, Q·125. Tena.is Blue 53.50 Trar"!0'99.625in. 53.Spl)l. 0 ·1 25

a. Double-click a non-editable cell pertaini ng to the Casing Shoe. The String Casi ng Shoe Data dialog box will display. ~ String Casing Shoe Data

--

- - -

@~

-

From Catalog..•

Geneial Desct4)fion ITraring 9.625 in, 53.5 pp/, Q· 125

Type

iJ

Mwadi.Im Model No.

ICamg Shoe ID.0708

bbl/ft

Closed End Displacement I0.0900

bbl/ft

lines Capacity

Length

12.00

ft

Makeup Torque

l25:m.o

Body OD

f9.625

in

Minm.Jm Ytekl Strength

1125000.0

Body ID

jB.535

in

Colapse Resistance

Approxinate Weight

Isa.so lo-125

pp/

Yoe;.ng's Modulus

l:mm:noo

Grade

P~'sR~io

10.300

Material

Jcs..APt scr

Density

14~

Comection

lnla

Float Option

..:.! :.:.!

ft·bf

psi psi

psi

lbm/ft'

Coeff. ol Thetmal El4?-

E-06/'F

..Only used by the Surge Module'"

r. Conventionel (Flow Out) Percent Alea Open

r

Autofil {Flow in and Flow Out)

j100.oo

TotelFlowArea 13.142

OK



Floet ID

Cancel

Apply

11

Help

5-23


b. Click Help to access the on line help to determine the difference between conventional and autofill options. The following is an excerpt from the online help.

Fl oat Option Area Use this section of the dialog to indicate what t ype of flow the float has (flow out only . or flow in and out) , the float inside diameter or total flow area. and the percent age of the float area that is open t o flow.

Conventional {Flow Out) or Autofill (Flow In and Flow Out) Check one of these option s to allow either the backflow of cement into or out of the casing.

o Conv entional (Flow Out} should be used if flow out of the workstring is possible, but flow in is not. For example, when running casing with a conventional float collar or float shoe.

o Auto Flow In and Flow Out should be used if flow in and flow out are both possible (for example. when running an Auto-fill type casing shoe). This t ype of shoe allows casing to be filled during running a joint of casing (to reduce surge pressure). After running that joint of casing. fluid inertia effects may result in flow out of the casing, hence flow in and flow out are both possible.

c. Select the radio button associated with the conventional option. TM

d. The WELLPLAN

software Surge module uses the float

option. This is indicated on the String Casing Shoe Data dialog box.

5-24

WELLPLAN ™ Software Release 5000.1. 10 Training Manual



29. Use Parameter> Standoff Devices to review the standoff devices. These are the rigid centralizers analyzed previously.

f:'

u.. St...ioff O..-.oe<

I

Seiect Froni CNi.Jo

COA' ~Uil'Cl tkz.• P*:ement

Ditl olf'C• ~ ro

s....

End

F' F' F'

fl' F' F' F'

00 351 986 Hl S

' " 34 2.t.7 JOll3 3533 406 4 4594 511.5

"' "'"' "'"' "' F' p

'2'52 "8 4 8317 985 1 938.4 9917 10452 1096.6

p

1152 1

F'

12056

fl'

1259.1 1312-7

F' F'

p p

F' p

"' p p p p

F'

"'

o...,

l~I

HI

fl'

Ae&.l!W"ffldlcln

~6

61aa 671.0

13643 1'193 U 7lS

1S27Z 156Q9 163< 7

lP 88.6 141

s

15' 4 2'73 J00.3

3513 406 4 459 4 5125 56"i 6 61&8 6no 725.2

7111 • 831.> aer. 1 939 4 991 7 10<52 10986 1152.1

1205 6 t
t.u s.s

uns 15272 1580.9 16341 1698 4

150 150 150 150 I SO 19'.l I so 150 I so I so I SO 1.SO 150 1 so 150 1 so 150 150 150 150 150 150 1.50 150 1 50 150 1.50 150 1 50 1 so 1.50 150

r....,. I 50 150 1.50 1 50 1 50 1 so I.SO 1 so 1 so I.SO I.SO 150 1.50 1 so 100 150 I 00

..1 "°""' 12.000 12000 12.00J

•2tnJ 12.tnl 12tnl 12.000 12 tnl 12 000 12000 12.000 12.000 12.000 12000 12.000 12000 12000

l 'i()

IZOOl

t so 1 50 I 50 I.SO I 00 150

12.00l 12.00J 1200) 12.00J 12.000 12.000 12000 12000

HO 1 so

Alf!Od

NoRl!jlld

o...... o

I SO

n.ooo

1.50

150

12000 12 000

1.!Jl

12000

1.50 1 so

12 000 12000

EHealMI

Uni•

.....

12.000 12 000 12.000 12000 12000 ll'OOO

mm

12.000 1aooo 12000 12000 12.000 n ooo n ooo 12.000 12000 12000 12000 12.000 12.000 12000 12.000 12.000 12.tnJ 12000

1.fOeNO ~St.mg,.crm

0

:i5° =

eo 0

u.

14000 12.000 12000 12.000 12.00l 12.00l 12.00J

~fcrc•

20

·ID

-40 I

1

y

0

10

Hole Diameter (in)



5-25


Determine Surge and Swab Pressures 30. The Surge analysis can be performed when the deepest pipe depth is Set at TD-90 ft. (one stand). If not an error message will be displayed in the Status Message window at the bottom of the application and calculations will not be performed. ~rg)

,;; Operation Data: -Swab/Surge - -

~

l_r.'~ I S~

Pipe Detais

ShoeDepth(MD)

j12500.0

rt

200:xl.O

ft

Additional MD of lnteiest

11500).0

It

Length ol Star.cl Pipe

j9'.J.OO

It

WelTD

D

Pipe Acceleration Pipe Deceleration

ft/see

ji.ooo

5..

lt/ieC

Addieional Options

r

4

ltlmri

It

rt1mn

It

ft/min

ft

It/min

..------ ft

ftlmtn

.. Pipe Depth should be in ascending Olde!

Flow OetMi

Use Low Cleaance Calculatiom'

(' Execution Time wil be long)

rt

FUd Editor...

P

I

Include Mud Tempeiature Erlects

CirculaOOg Fluid

Flow Rate OK

jr-1-3.8_ ppg _ 0_8_M_.1-3.80- ppg - - -3-. ...

jo.o

Cance:_j

gpm

Apply

Heb

a. Specify the operation data using Parameter> Operations Data

5-26




b. Consider analyzing pressured zone(s) in the open hole section. In this example, the Case> Pore Pressure spreadsheet indicates a pressured zone at 10,743 ft TVD. ,,..

EM\o/

l 600.0 U 76.0 1804.0 1969.0 2297.0 3181 .0 3279.0 3344.0 3764.0 4505.0 4624.0 4712.0 511l8.0 53440 54800 5680.0 5801.0 6475.0 7355.0 7798.0 8281 .0 8767.0 SZ5S.O

7.17 7.57 782 7.92 8.07 a49 8.51 852 8.60 aS9

223 4 580.5 7'12.7 8101 9624 1403.3 H49.8 1479.6 1681 5 20343 2176 1 2285.5 2511 5 2762.6 296'5.5 3211 9 2738.2 3069.4 3610.7 4071.1 4577.3 4939.6 5363.0 5499.0 6109.1 6239.2 637o.5 6584.7

9493.8

$00.0 9725..0 9850.0 10100.0 102540

9.~

9.34 9.47 9.95 10 42 1089 9.09 9.13 9.45 lo.OS 10.64 1085 11.15 1115 12.25 1235 12.45 12.55 12.65 12.75 1125 13 30 13.34 1138 13.42 1146 13.50

673a3 69572

1jrfil~ I

7395.1 m 4.S 8144.7 8516.6

11753.0 12253.0 125030 12753.0 13243.7

8716.4

8917.2 9287.8

v

Press FU to access the Convert Depth/EMW dialog box and use it to determine the MD corresponding to this TVD. l0,743.8 ft TVD corresponds to 15,000 ft MD. - -

1p1

IBJ

Convert Depth/EMW

Depths

MD ~ftl j 1sooo

T\ID ft 107'13.B

tielp Pressll'e/EMW Pressure (l>Sl)

EMW(PPQ)

Pore Pressure

17395.05

f13.25--

Fracture

18304.60

j 1<1.B8

Open Hole PresSU'e Limits Pressure (psi)

Max. Pore Min. Fractll'e

Im1.6'1 !m 4.4s

I T\ID (~) j t32'13.78 19493.76

c. Because you are running a liner, a stand of pipe is 90 ft.



5-27


d. The deepest pipe depth is not at TD because a surge analysis cannot be performed if the bottom pipe depth is within a stand length of TD. If so, a message will be displayed in the Status Message section at the bottom of the application window, and calculations will not be performed. 31. The formation is fracturing at some depths of interest using one ormore moving pipe depths. Notice on the following plots the depth of interest is indicated in the plot title bar. Each curve on the plot represents the pressures or EMWs over time at that particular depth as bottom of the liner is at a specific moving pipe depth. Use the legend to determine which moving pipe depth corresponds to each curve. If a curve crosses over the red line at the top of the plot, the pressures or EMWs are fracturing the formation. Conversely, if a curve crosses over the green line at the bottom of the plot, the pressures or EMWs fall below the pore pressure and a kick may occur. a. Use View> Operation Plot> Transient Response Plot) to review the transient pressures/EMWs at all moving pipe depths as a function of time. Right-click in the plot to access a menu that can be used to select a plot at a different depth. You can choose to display the data as EMW vs. Time rather than Pressure vs. Time.

5-28




1BO

1500

1• ~o

Ci 0.

~ ~ 1•00

a;

.,,~

~

..

1350

c

'lV ~

:>

1300

C7

w

1250

1200

1150

..... -...... " ••Mf'0• 12i8tt l 0 OCO

0 050

0 100

0 150

0 200

0.250

0 300

0 350

0 • OO

0 • SO

T1melmml



0 500

0 5!50

0 600

0

"°

0 700

0 750

0 800

O 850

5-29


The following plot displays the results at the depth of interest ( 15,000 ft MD) for all three moving pi pc depths. Notice that the form ation fracture gradient is exceeded at this depth when the pipe depth is at the shoe or the depth of interest or near TD.

15 50

-a Q.

.s. ?:

2' 1500

~ ~

::>

~

..

c

'i6 1• 50

>

~

w

1'00

0

1350

0000

0050

0100

0150

0200

OZ50

0300

0350

O•OO

0•50

Time (ITln)

0500

0550

0500

0550

0700

0750

0800

0850

Using the right-click menu again, di sp lay the resul ts at TD. Notice the fracture gradient is exceeded when the pipe is at 19,9 10 ft MD, and also

5-30




slightly into the red zone when the pipe is at the depth of interest (15,000 ft MD). LE Of ND -&-1~0ft-tS50Mm

-6-

~

1~000011- t~!Oft/ril

199100 ft · •550ftl-

1&50

1600

14 50

1350

0000

0050

0 100

0 150

0.200

0250

0300

0350

0 ' 00

0450

Time (mm)

0.500

0550

0600

0650

0700

0750

0800

0850

b. Freeze the curves that are fracturing.



5-31


32. Use Case> String Editor to change the float option to autofill.

FromCat~ ..

J

General Desaiption jr rllining 9..625 '1. 53.5 pp/, Q·l 25

3

Manulacturei

ICasino Shoe

Type

Model No.

ll

Body ID

12.00 19.625 18.535

ll

Collapse RestStance

Approxinate 'Wei<;#

153.50

pp/

Young's Modulus

Grade

IQ·125

Material

lcs_API 5CT

Connedioo

ln1a

Length Body OD

ft

3 3

10.o?os

Lnear Capacity

bbl/ft

ClosedEndDrs~ I0.0900 Makel.C> Torque f25390.0 Mrnim.m Yield Strength 1125000.0

bbl/ft ft·lll

I3COOXJOO.OO 10.300 1 4~

Poisron's Ratio Density

bn/ft'

Coeff cflnermalExp.

E-C&''F

Float Op00n ""Only used by the S1.1ge Moduler Conventronal (Flow Out) r. Autofrll [Flow In and Flo_ w_ O_ ut~ ) Float ID

I

Peicent Asea Open f100.oo

ll

Total Flow Asea OK

I _:_ance1_J

13. 142 Apply

Help

a. Yes, there is still the possibility of exceeding the fracture gradient at TD when the moving pipe depth is at TD. L EGEND

-+- 1W,OO ft.1sso ftlml'I

FrNH

- - ISOGOOft-ISSOftlnwl:fruzo -G-1~0ft·l~SOM!ln_f1uu -a-12socoft .1~o ftlnwl

- - 1S0000ft ·1~0 lllmn

- t - 11t1oon.1!SOIVfM

16.00

1450

1• 00

13 50

0000

0050

0100

0150

0200

0250

0.300

0350

0400

0 450

0.500

0550

0.600

0650

0700

0750

Time(mn)

5-32

WELLPLANTM Software Release 5000.1 . 10 Training Manual


0800

0850


b. The largest reduction, about 2.1 ppg, occurs about 0.6 minutes into tripping the stand. Click the Data Reader icon on the tool bar to assist you.

0 000

0 050

0 100

0 150

0 200

0250

0 300

0 350

0

"°°Time0(min) 450



0 500

0 550

0 600

0 650

0 700

0 750

0 800

0 850

5-33


c. Yes, there is s till the possibility of fracturing the formation.

14 50

Ci

~ 1350

:c OI

~

-g

1300

2

..

c

(ij

>

~ 1250

w

12.00

1150

0000

0050

0100

0150

0200

0250

0300

0350

O•OO

0•50

0500

0550

OMO

0650

0700

Time(mm)

5-34

WELLPLAN TMSoftware Release 5000.1.10 Training Manual 恭贺新禧! http://www.egpet.net ‫ﺷﻛرا ﻟك‬

0750

0800

0850


d. Yes , there is still the possibility of fracturing the formation at 15,000 ft. d-·15000Ct

1480

1480

O

1H0

Q.

.e

~

~ 1420 "O

::> ~

~

1ioo

i6 > 5

CT

w

13 80

1360

1340

0 000

0 050

0 100

0 150

0200

0.250

0 300

0.350

0 400

0 •50

T1me(min)



0 500

0 550

0 800

0 650

0 700

0 750

0 800

0 850

5-35


Check the Tripping Schedule 33. Review the tripping schedule using View> Operation Plot> Trip Schedule. a. The Trip Speed at TD= 122.6, Shoe= 132.6 and Depth of interest= 131.0 ft/min.

1lOOO

r::::-1 t.=:::.=.J

13000

--

LEGEND

-

u_...

frK

- · • Pore

1'000

g

15000

'O lllOOO

;..

~"'

5

17000

0:

18000

lllOOO

20000

~ee...- - · . 122

12'

128

12t

130

132

13'

Tnp Speed (ftlrnn)

20000

1150 M1mmum T np Speed

5-36

ji2i"8 ft/min

Ma.>amum Tnp Speed

!iJ50 I/mm

1200

1250

1300

1350



1400

EQUMJlel'i Mud Wetghl (ppg)

1• 50

1500


b. Freeze the trip speed curve generated using autofill. Using a different tab, access the String Editor and change the float option to Conventional. Review the Trip Schedule plot again, and notice the trip speeds must be significantly reduced using the conventional float option.

13000

13000

14000

g

1400-0

15000

15000

~

c!l 'O .,:i~ "' ~

Otpllol~t
16000 1&000

c: 17000

&.

17000

18000

18000

19000

70

80

90

100

110

120

130

Tnp Speed (II/mm)

20000 11 so

Mi"'mum I np Speed~ - 11/mri

Maximum TnpSpeed~ II/mm

1200

12 50

1l00

13-50

14 00

14 50

15 00

EqUIV81enl Mud Weight (ppg)

c. Enable auto-fill before proceeding.



5-37


34. First, use the Parameter > Operations Data dialog box to specify the revised trip speeds for each moving pipe depth. Then, review the View > Operation Plot > Transient Response plot at each depth. Notice the problems are resol ved. ~[g'J

IP Operation Data: Swab/Surge Operation

..;- St.rge

r" Swab

PipeDet~

Shoe Depth (MD}

'12500.0

ft

\I/el TD (MD)

j200Xl 0

fl

Adcibonal Depth ol lnteiest l1500l.O ft Length ol Stand .90 - .00 - - - - ft

Pipe

J

Pipe~ation

11.000 11.000

P1pe Deceletabon

ft/sec' It/fee'

~(MDC

ft

Pipe Speed l125 q

fVrr.l

ft

11200

IVITSI

3Jl199100 - - ft

1115.0

IVmn

ll

2Jl1sroio

41 1

ft

fVrr.l

5)

ft

rvmin

I

··Pipe Depth shoUd be tn atcendtng °'der

FlowDelaa

Mcit>onai Options

r

Optmze Tii> Speed

r

Use Low Clealance CalWabons'

Fled Edit°' ~ Inc~ Mud T~ah.Ire Eltects C.~

I"ExecUion Trne W11 be long)

Fled

...

,-1-3.8_ppg _0_8_M_.1_3._ 00_ppg _ _ _3~

Flow Rate

jo.o

OK

!Pl'l Apply

I_ H~

Results at the shoe do not indicate a problem.

1'50

1400

i

1350

~

~

~ 1300

t

11

5->

1250

w

1200

1150

()()()

5-38

010

020

0 lO

040

050

T1me(mm)

060

070

080

090



100


Results at the depth of interest, 15,000 ft, do not indicate a problem.

14 80

1'60

Ci a. .9:

~ 1~20

£ -g ~ c

1400

41

1il > 3

CT

w

1380

1360

13•0

000

010

0.20

030

O•O

050

060

0 70

080

090

1 00

Time(mm)



5-39


Results close to TD do not indicate a problem.

000

5-40

0 10

020

030

O• O

050

T1me(mm)

oeo

070

080

090



t 00


Reciprocating 35. Select the Reciprocation analysis mode using the Mode pulldown list. 36. Specify the analysis parameters using Parameter>

Operations Data. 'P Operation Data: Reci~rocation

-

~Detais

-- ---- -~

r7][8)

Retj'.xocaion Depths

It

Shoe Depth (MD)

j12500.0

fl

1) Aec\'.>location Depth

WelTO(MD)

r200XJ.o

ft

2) Reqxocation Depth

It

ft

3) R~ocallon Depth

It

4) Aec\'.>locabon Depth

ft

5) Reop(()calion Depth

ft

Acldibonal Depth ol lrtei8$I Veloaly Profile DMe

jo.soo jo.500 lno

Pipe Acceleration Pipe DeceletMion

AeoprOOllbon Length Aeopioc:aOOn Rate

r

ft/tee

Flow Detail

ft/see

~

J

FUdEciOf

ft

11.00

P

lrdJde Mud Tempeiature Elferu

ucoAaling Fkid

Use Low Clealance CalcoJabons

119975.0

113.8 ppg OBM. 13.80 ppg

jo.o

Flow Rate

OK

I-

Cancel

"""3 gpm

~

Help

37. The EMW falls below the pore pressure at TD while reciprocating.

000

050

, 00

, 50

200

Time(mtn)



250

300

350

4 00

5-41

)


38. Use Parameter> Operations Data to specify the flow rate. Yes, the issues are resolved.

1p1

ff][E)

Operation Odta: Reciprocation

PipeOet!IU

Rec1P
119975.0

ft

Shoe Dep(h (MD)

1125000

fl

WelTD (MO)

l200Xio

It

2) Aeapr~ Depth

It

3) Aeapr~ Depth

It

41A~ocatoon Depth

ft

5) A~ocatoon Depth

ft

Adiioonal Dep(h ol lnteiest Velocity Prolie Data Pipe Accelefation Pipe Decelefaoon RecPocatoon Length Reciprocation Rate

lo.soo jo.soo 122.o j1 00

ll/;ec' ft/sec'

ft spm

r U:e low Cleatance CalcWbom

1) Aeaprocatoon Depth

It

Flow Oetais FM.id Elita

r;; Jrd.Jde Ml.Id f e111>CfalUle Effects Circulal~~

~

I FlowAate

OK

~

I- -

~

LE GEND 19975.0ft(TVl>•132312 ft)

14.10

14 00

Oi 0.

.9; , 3.90

§ w

13.80

13 70

13.60

13.50 000

5-42

WELLPLAN TMSoftware Release 5000.1.10 Training Manual


.1

h38 j ! :M. 13.00 pps

Apply

J

Help

I


Condition the Well Prior to Cementing (Using Hydraulics Module) 39. Access the Hydraulics mod~le by clicking the

Tel toolbar icon.

40. Use the Mode pull-down list to access the Pressure: Pump Rate Fixed analysis mode. 4 1. Use the Parameter> Standoff Devices dialog box to indic ate standoff devices (centralizers) are not used in the analysis.

I

Selecl From Cataog

{ft)

F7 F7 F7

IV IV 17 F7 F7 F7 F7

F7 F7

IV Cerolr.,;, IV Centr~ CMtr~ Centr~

F7 F7

F7

Centroize< F7

Centroizer F7 Cerlralizer F7 Centraizer F7 Ceooaizer F7 Centlaiter F7 F7 F7

F7 p IV IV F7 F7 F7

(ft)

00 35.7 896 141 5 194 4 247.3

:m.3 353.3 406. 4 459.4 5125 ~6

s1·s .e 672.0 725.2 7784 831.7 885.1 9384 991.7 1045.2 1098.6 11521 1205 6

1259.1 1312.7 1366.3 1419.9 1473.5 1527.2 1580.9 1634 7

J

Copy horn U.rbaizef f'lac:emert

Dmance hem TO Slarl End 357 BB.6 141 5 194 4 2473 lll3 3533 406,4 459.4 512-5 565.6 618.8 672.0 725.2 779.4

831.7 885.1

938.4 991 7 1045.2 1098.6 1152.1 1205.6 1259 1 1312.7 1366 3 1419.9 1473.5 1527.2 1580.9 163.U 16884

Relative FrlCtiorl Drag

1 50 1.50 1.50 150 150 150 150 1.50 1 50 1.50 150 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50

1.Sli 1.50 1.50 1.50 1.50 1.50 1 so

TOlque

150 150 150 150 150 150 150 150 , 50 1.50 1.50 1 50 1.50 1.50 150 1.50 150 150 150 150 150 150 1.50 1 50 1 50 1.50 150 1.50

1.50 1.50 1.50

1 50

OutsideOoame!er Adual Effectiva 11'1

1200l 12.00l 12003 121))) 121))) 12000 12000 12000 12.00l 1200) 12.000 12 IXXJ 12.000 12.000 12 00'.J 12000 12 00l 12000 12 flXl 121))) 12.CXXI 12.00l 12.000 12 1))) 12000 12.Coo 12000 12.IXXJ 12.000 12 000 12.000 12.00J

Fr

fl'I)

12.000 12.000 12.000 12.00l 12.00J 12000 12.000 12.000 12000 12000 12.0ll 12.000 12.tm 12.tm 12.lm 12.0CWl 12.000 12.((W) 12.000 12.00J 12.000 12.000 12.000 12.r;nJ 12.tm 12.000 12.000 12.IXXl 12.IXXl 12.IXXl 12.000

12.IXll

c

20

g Q)

~

0

0

u. 1 1 1 1 1 1 1 v

·20 ·40

0

50

Hole Diameter (in)



5-43


42. Determine how long it takes to circulate two circulations. Press F12 to determine the annular volume. Using this volume, it will take approximately four hours to circulate one time. 1p1

Volume Calculations

-

I0 .0 Base I20000.0

Amulus

1.-1-32_4_3-.7- -

- .:::J

1738.83

Pipe

I0.0

tielp

2055.55

Total

f'2794.37

Between strings

I0.00

C8:J

-

Volumes (bbl)

Depths (Capacity Range) MO (ft) TVO (ft)

Top

-

43. Use Parameter> Rate to specify the analysis parameters.

Quick Look

Pl.fnPData ~Rate-

l•oo.o

Stand Pipe P1au1.1:e:

11267.38

PSl

Ma>
j75oo.oo

psr

Surface EQO.ip Piem.Je L~.

12000.00

hp

Bit Prem.re Lon:

j100.00 jo06

psi

Maxmm Pl.fnP Power

Bt Impact FCllce:

16"4

l:if

Bit Hydraulic Powei·

JOOl

hp

Percent Power al Bit

10.00

%

HSI:

10.0

hp/in'

B~ Nozzle Velocly:

j2-2

ft/$

0 btaii from Ciculatng System Atnju;

Pipe

r r r

Use Roughness Include Tool Joint Pressue Losses Include Back P1esSU1e Back Preu...e.

P

...

Total B~ Flow Area(L~.

I

rd

Pump Rate:

j400.0

gpm

psi

Include Mud Tempe1al1.1:e Effects

Time°' Circulation: jB.oo

r

I

in

hr

Ret...ns al Sea Floor Sea Wate1 Density

I

r


r-

Use Strl'lg EdtCll B4 Noll!es

ppg

OK

5-44

psi

Cancel

I -·~



H~

j

J


44. Use View> Plot> ECD vs. Depth.

L EG END _.,_ Anrd.ls 0 Pore A -

free

0

2000

4000

6000

g

8000

5

a. Q)

0

10000

'O

~

::;,

(/)

(t> Q)

12000

~

14000

16000

18000

20000

7.00

7 50

9 00

8.50

9.00

9 50 1 0 00 10 50 11 00 11 50 12.00 12.50 13 00 13 50 14 00

ECO (ppg)



u

50 15.00

5-45


45. Use Parameter> Rate to include tool joint pressure losses by checking the Include Tool Joint Pressure Losses check box. - -

~- ~ te _____

---------- -

-

P~Data

-

- ----

--

1400.0

gpm

Stand Pipe Pteuuie:

Ma>Gmum Sl.fface Pressure:

17500.00

psi

Surface Equip. Pre$Sl.le Loss: j100.00

Mallinun Pl.lllP Power

12000.00

hp

Maxm.m Alowable Pl.lllP Rate·

gpm

Obtaii from Cictkting Syuem Options p~

r

... I

P'

lnck.Kle Tool Joiit PreutSe Losse;

r

Include Back Pressure Back Pteuure:

P

j1soo 63

psi psi

Bit Ptesst.re Loss:

loos

Bit Impact Force:

j6.4

bf

B~ Hyciau&c Powe1:

f0.01

hp

Perceri P0¥1er at Bil

1000

4

HSI·

Ina

hp/in'

Bit Nozzle Velocity

122

IVs

Total Bit Flow Ar~~

- - psi

~

.....--- psi

lnc:We Mud TempeiattSe Effects

Time o1 Crctktion: la.oo

r

IT} ~

Quick Look

Pl.lllP Rate-

r useR~

-----

hr

P~Rate:

j400.0

gpm

Retims at Sea Floor SeaW!!leiDensity

ppg

.- lock.Ide Ci.ibngs Loadng r- Use String Editor B~ Nozzles

0K

5-46

I- Cincel



Help


Click the Rescale icon on the tool bar to enlarge the portion of the plot containing the curve data. Notice the tool joint pressure losses increase the ECD as depth increases because the tool joi nts reduce the annular volume. A too] joint may also result in reduced internal pip volume if the tool joint ID is less than the pipe ID. rljldroum;. f'Je.:ure

f'l.KlJ> Rote foe(!· ECD vs

Depth

__ _

LEGEND ~ ~

Arn;kJs

0

P<>re

A

AlnJlls

Free

11000 12000 13000 14000 15000 16000

g .r:::. a.

17000

0

18000

(])

"O

~

::> 19000 Ul

ro

Q)

~ 20000

21000 22000 23000 24000 25000 26000 13.900

13-950

H .000

U.050

14.100

ECO (ppg)



14.150

14.200

14.250

14 300

5-47


46. Include the centralizers by checking the Use Standoff Devices check box on the Parameter> Standoff Devices dialog box. The centralizers also reduce the annular volume. The increase begins at 15,000 ft because thar is where Lhe centralizers begin. H.lodr~ : Pr~ :U1eP\JT,pRateFaced ECD ~ C• epth

_

_

_

_ ____

_

____

--~

LEGEND

0 0

AIYUJS

ArtUus ·'Mil TJ Arn.JAJs Pore - i> - Frac O AroJus . v.th C«Wral?ers

<> a

12000 13000 14000 15000 16000

E'

£0. 17000 Q)

0 "O

18000

~

::J (/)

19000

(I) Q)

~ 20000

21000 22000 23000 24000 25000 26000 13.900

5-48

13.950

14.000

14 050

14.100

ECO (ppg)

14.150

14.200

14.250



14.300

_


47. Review the geothermal data using View> Plot> Geothermal Gradient. The circ ulating temperature at TD is 209 degrees F, and the return temperature at the surface is 75 degrees F.

LEGEND

-

Gedllermel

O

Mean Sea level • 1 CXUl ft

Slri'lg -Arna

g

5000

£

a. Q)

0

"O

10000

~

:::>

r.n

ro

Q)

~

15000

20000 40

60

80

100

120

140

160

180

200

220

Temperature r F)

r;; Include Mud Teq>eialure Effects Tire ol CicUation

WEL LPLAN™ Software Release 5000.1.10 Training Manual


ls oo

5-49


5-50

WELLPLAN™ Software Release 5000.1. 10 Training Manual 恭贺新禧! http://www.egpet.net ‫ﺷﻛرا ﻟك‬

Chapter

ID

Cementing the Liner Overview Data The data used in this exercise is not from an actual well. Although an attempt has been made to use realistic data in the exercise, the intent when creating the data set is to display as much software functionality as possible. Therefore, some data may not be realistic. Please do not let the accuracy of the data overshadow learning the software functionality.

Workflow In this section, you will cement the 9 5/8" liner you analyzed in the previous workflow. The workflow begins with a review of the centralizer placement determined in the previous workflow. The bottomhole circulating temperature is estimated. Entering of cement job data is performed using fluids provided. Result analysis includes analyzing: circulating pressures, downhole pressures, density and hydrostatic profiles, comparing rates in and out, wellhead and surface pressures, and estimated hookloads. Hole cleaning (erodibility) is investigated, including the effect of remaining mud on fluid tops. The animation is used to determine flu id tops, volumes, and other cementing parameters.



6-1

Chapter 6: Cementing the Liner

Workflow Solution Solutions for the workflow steps in this chapter can be found in the Cementing Solution chapter.

What Is Covered • • • •

• • • • •

• •

6-2

Integration between WELLPLANT~ software modules Defining cement slurries and spacers Different placement methods Defining a cement job, including: -

Sequence and rates fluids to be pumped

-

Plugs

-

Shoe tracks

-

Automatic Rate Adjustments and Safety Factors

-

Job stages

-

Cement material requirements (sacks)

-

Displacement volumes

Surface iron works Estimating bottomhole circulating temperatures Determining pipe and annular volumes Specifying a gauge or washed-out hole Using many of the available plols (as a funclion of time, volumes, and strokes) to analyze:

-

Circulating pressures

-

Downhole pressures

-

Density and hydrostatic pressure profiles

-

When "free fall" is occurring

-

Wellhead and surface pressures

-

Hookloads during the job

Fluid Animation when reviewing many job parameters Hole cleaning during the cement job

WELLPLAN TMSoftware Release 5000.1 .10 Training Manual



Open the Case 1. Open the case titled "Cement Liner." You will be cementing the 9 5/8" liner you analyzed in the previous exercise. Note If you have a Halliburton® OptiCem '"' OTC file , you can import this data directly into an open WELLPLAN case using File> Import. You can create a case using File > New > Instant Case.

2. Activate the OptiCem module and the Wellbore Simulator analysis mode. 3. Keeping in mind the data integration provided by the WELLPLAN software, what data type of wellbore data do you think you will need to input to analyze a cementing case that you did not input in the Running Liner case?



6-3


Input and Review Wellbore Data Review Hole Section, String, and Wei/path Data 4. Review the hole section data. Is the hole washed out? Note Caliper log data can be directly imported into the H ole Section Editor using

File > Import Caliper.

5. What is the total annular volume and the annular volume in the open hole? Why is the Between Strings volume zero? 6. What is the total annular volume and the annular volume in the open hole if there is a 15% washout? 7. Set the open hole back to gauge ho le. 8. Review the string data. 9. Review the Wellpath Editor. Is tortuosity used ?

I

Hint

Clkk Options.

Define Cement Slurries and Spacers 10. Input the fo llowing fluids. All flu ids use the Bi ngham Plastic rheology model. The 13.8 ppg OBM should already be input because it was used in the previous exercises. Name

Type

Class

Density (ppg)

PV@70 degrees

YP@70 degrees

Yield (ft3/sk94)

Water Req (gal/sk94)

14.0 ppg Spacer

Spacer

n/a

14.0

28.0

12.0

n/a

n/a

14.5 ppg Lead

Cement

H

14.5

39.0

9 .23

1.36

5.91

I 6.4 ppg Tail

Cement

H

16.4

178.3

19.8 1

I .4 I

8.35

6-4

WELLPLAN TM Software Release 5000.1.10 Training Manual



Review Pore Pressure and Fracture Gradient Data I I. Review pore pressure data. Where is the maximum pore pressure in the open hole section? 12. Review the fracture gradient data. Where is lowest frac ture gradient in the open hole?

Review or Input Geothermal Gradient Data 13. What is the s tatic bottomhole temperature?

Review or Input Circulating System Data 14. Review circulating system data. What is the displace ment volume in the surface iron?



6-5


Centralizer Placement You can use multiple types of centralizers. You can create a "pattern" of centralizers. For example, you can alternate between two types of centralizers, or use two of one type of centralizer followed by another type. There are several patterns available for use. 15. Review the centralizer placement. Notice these are the same centralizers used in the previous Running Liner case.

Specify Depths of Interest 16. Specify the depths of interest based on your answers to Steps 11 and 12. Why use these depths?

6-6




Estimate Bottomhole Circulating Temperature It is strongly recommended that the circulating temperature profiles be run using a temperature simulator as in WELLCAT software (HCT file) or data obtained from a cementing service company. (Click Edit Profile to input or import a temperature profile.) If this data is not available, a quick temperature analysis can be run using the WELLPLAN Hydraulics module. For this exercise, you do not have an HCT file, or other data, so you will use the Hydraulics modu le for a quick estimate of the bottomhole circulating temperature.

17. Activate the Hydraulics module and the Pressure: Pump Rate Fixed analysis mode. 18. Specify a flowrate of 400 GPM. (This is the same flow rate used to condition the hole in the Running Liner case.) Include the effects of mud temperature in the analysis. Circulate for nine hours. This allows for approximately two circulations. 19. What are the circulating annular bottomhole and surface temperatures?



6-7


Input Cement Job Data 20. Activate the OptiCem module by clicking the OptiCem toolbar icon ( El J ). Select Wellbore Simulator from the Mode pulldown list. 2 1. Input the BHCT, surface temperature, and mud outlet temperature. 22. Specify the following cement job data using the Parameter >Job Data dialog box. Notice that all fl uids are pumped at I0 bbl/min except for the tail slun-y. Note Plugs indicate the start of the displacement, as well as act as a normal plug. In OptiCem, Top Plug with the New Stage check box checked indicates the start of displacement. In this exercise, the second stage of the tail cement is an optional step to speci fy the time to drop the plug.

• As the wellbore fluid, use 13.8 ppg OBM. Specify a rate of lO bbl/min. (Because this fluid is designated as the active fluid on the Case > Fluid Editor, it will display in the top row of the Job Data dialog box by default.) • Use 50 bbls of the 14 ppg Spacer as a spacer. Pump the space r at 10 bbl/min. (Select Spacer/Flush in the Type pull-down list.) The Placement Method is Volume. • Pump the 14.5 ppg Lead cement at a rate of 10 bbl/min. The Placement Method is Top of Fluid. Specify the top of the lead cement at 12,250 ft (at the Liner Hanger). (Select Cement in the Type pull-down list.) • Pump 2,000 ft of the 16.4 ppg Tail slurry at a rate of 7 bbl/min. (Select Cement in the Type pull-down list.) The Placement Method is Length. • Drop a plug. To do this, add a second row of 16.4 ppg Tail slurry. Uncheck the New Stage check box so that this entry becomes the 4-2 stage of the tail slurry. Specify a shutdown time of five minutes to drop the plug.

6-8




• Indicate the start of the displacement by se lecting Top Plug as the Type for the row between the tail cement and the d isplacement fluid. C heck the New Stage check box. • Pump 10 bbls of 14.0 ppg Spacer at 10 bpm, on top of the plug as a post flu sh, as an extra measure to prevent slurry contamination by di splacement mud. • Select Mud in the Type pull-down list. Displace the cement with the 13.8 ppg OBM mud pumped at 10 bbl/min. • Because the annulus is open to the atmosphere, use 14.7 psi for the Back Pressure and 0 bbl Return Volume . • Use 80 ft of shoe track. • Select the Top Plug option and enter 350 psi for bumping the plug. •

Do not auto matically adjust the rates.

•

Do not use foam cement.

•

Do not use Inner String.

•

Enable auto-displacement calculations. (Leave the check box unchecked.)

a. How much shoe track volume is predicted?

b. How many sacks of lead and tail cement are needed for this job? c. If the shoe track was 160 ft, how many extra tail slurry sacks would be required? It is important to set it back to 80 ft after checking. 23. What is the displacement volume? 24. What is the pipe volume, and why does the displacement volume in the previous step not equal the pipe volume?



6-9


Analyze Results Review Circulating Pressures 25. Do the circulating pressures (vs. volume) during the cement job exceed the fracture pressure at the shoe? 26. Do the circu lating pressures (vs. volume) cause a well control problem during placement at TD?

Review Downhole Pressure Profiles 27. Access the View> Plot> Downhole Pressure Profiles plot. a. What would you use this plot for? b. Is it possible to take a kick or fracture the open hole during the cement job? c. What does the minimum hydrostatic gradient curve represent? d. What does the maximum ECD curve represent?

Review Density and Hydrostatic Profiles 28. Access View > Plot > Final Density and Hydrostatic Profile. What do the curves represent?

Compare Rates In and Out 29. Access View> Plot> Comparison of Rates In and Out. View Results vs. Time. a. What does this plot represent? b. Does "freefall" occur during the job? c. Is the predicted free fall a cause for concern in this design? d. What does the Gas Rate represent on right side of the plot?

6-10




Review Wellhead and Surface Pressures 30. Access View> Plot> Calculated Wellhead/Surface Pressure (in Time). a. What is the maximum calculated wellhead surface pressure and when during the job does it occur? b. What is the difference between the pump pressure and the wellhead pressure? c. What is the maxi mum calculated pump pressure? d. Why does the pressure initially drop, and then increase?

Review Hookloads 3 1. Access View > Plot > Hook Load Simulation. a. Is there any danger of pumping the non-secured pipe out of the hole during the cement job? b. Is the rig capacity exceeded? c. Remove the line of interest from the plot. When is the maximum hookload predicted during the job?

Use the Fluid Animation to Analyze Job Parameters 32. Access View> Fluid Animation Schematic. a. Do not include any labels on the animation, and view the animation using a 112 cutaway. b. Set the down hole pointer to 19,000 ft annulus (the mid-point of the tail slurry) . View the schematic To Scale. c. Review the colors associated with each Ouid. What color is associated with tail, lead, spacer, and free fall? d. Run the simulation. What volume has been pumped when freefall occurs and the Time In is 54 minutes?



6-11

) Chapter 6: Cementing the Liner

e. What is the bottomhole pressure and ECD at 19,000 ft (annulus) when free fall begins? f.

Finish the simulation.

g. What is the total time to pump the job? h. Why is knowing the time required to pump the job important?

Review Hole Cleaning Erodibility data should be obtained from field studies, the mud company, or lab tests. If you do not have centralizers in the analysis, and you enable the Eccentricity option, the pipe is assumed to be on the low side of the wellbore. 33. Enable Erodibility and Eccentricity analysis. Specify a required shear stress (l bf/100 ft2) of 20 for this exercise. Analyze between a top and bottom measured depth of 18,000 ft and 20,000 ft, corresponding to the tail slurry placement. 34. Access the View > Plot > Erodibility Profile plot. What is the displacement efficiency in the tail slurry section of the annulus? 35. Analyze the entire open section in the annulus. a. Access the Analysis Data dialog box, and select the Entire Open Hole Section radio button. Click OK to re-run the calculations. b. Is the wellbore clean or is there mud cake remaining? Why is there an increase in mud cake between the previous shoe and 15,000 ft? c. ls the remaining mud cake a problem if only a good tail cement placement is required? d. If a mud cake remains, what parameters, other than hole cleaning, should be re-examined?

6-12




Fine-tune the Job Re-examine ECDs 36. Use the Downhole Pressure Profile plot to determine how erodibility affected the ECDs in the open hole. Where is the increase in ECD most likely to cause a problem? 37. Change the fracture zone of interest from 12,500 ft to 20,000 ft. 38. Is the circulating pressure close to the fracture gradient? 39. Add a safety factor of 150 psi using automatic rate adjustment. 40. Is the circulating pressure still close to the fracture gradient? (View in volume.) 41. How have the rates changed, and how many barrels will be pumped at the lower rate? 42. Access View > Plot > Downhole Pressure Profiles and notice the maximum ECO is not as close to the fracture gradient as it was prior to the rate adjustment.

Re-examine Fluid Tops 43. Now, you will examine the Lop of fluids. Run the fluid animation at 19,000 ft annulus with erodibility.

a. What does the red color remaining in the annulus at the end of the job represent? b. What is the predicted top of the lead slurry with the mud remaining? c. What is the revised predicted top of the spacer with the mud remaining?



6-13


6-14



Chapter.

Cementing the Liner Solution Overview This chapter contains the answers to the exercise questions presented in the Cementing the Liner chapter.



7-1

) Chapter 7: Cementing the Liner Solution

Open the Case I. Use the Well Explorer to open the case.

2. Click the OptiCem toolbar icon ( 0 j) to activate the OptiCem module. Select Wellbore Simulator fro m the Mode pull -down lis t. 3. The WELLPLANTMsoftware is a suite of integrated engineering applications that share data stored in the EDMrMdatabase. Once data is input, it is shared between applications as appropriate. Data stored in the EDM database can also be shared with other Landmark® applications. Refer to the online help for more information about integration. In these exercises, you are using data already entered in a previous exercise. Data already entered includes: • • • • • • • •

Hole section data String data Wellbore fluid geothermal Wellpath Pore pressure and fracture gradient Shared centralizers Shared rig data

Data specifically related to a cement job, that must be entered for this exercise, includes:

7-2

•

slurries and spacers defined using the Case > Fluid Editor.

•

the sequence and volume of fluids pumped during the cementing operation input using the Parameter > Job Data dialog box.

•

other analysis parameters specific to a cementing analysis.



Chapter 7: Cementing the Liner Solution

Input and Review Wellbore Data Review Hole Section, String, and Wei/path Data 4. Use the Case> Hole Section Editor. No, the hole is not washed out. To indicate the hole is washed out, specify the percentage increase using the Excess(%) field.

H"' N-

JHoie Section

H"' S.cl.oon Deoth (MOt

l:mno MeM<.ted

SeebonT~

08lllh (fll

sso o

Shoe

Ler9h (II}

590.00

r

1.zsooo 11sinoo r mxio 7500.oo r

12500.o

10

Onft

(nl

lnl

1aooo 1Z37S 1Z25il

1ZBl

Fni;IJotl Facia

17500

12.250

0.20 0.20 0.:.1

i.ne.. ~

lbbllftl

Ex=s

ltemOO>CtiPCIOll

I~

M..UllC:Mer

Model

0.3147 RSA SedJOn. 20nx 18 n 0.1489 CAS 13 518 ir1. 88.2 Pill. Q· 4!.1458c=::::filID:iH 12 112"

r

5. The Between Strings volume pertains to an inner string configuration. If there was an inner string confi guration, this volume is the volume between the inner and outer strings. Hint Use Tools> Volume Calculations.

The total annular volume is 2,055 bbls . ~

., VolllfM Ccalculatlom ~(bbl)

~(CAocty~)

I'll (It)

o.o s- jzcooo.o fop

M)

t)

00

I 13:-4).7

Pcie

~ TU

J738 83

!

21l5S SS

Help

2794.37

8«...e«i Sbf'IQS 0 lJO

The annular volume in the open hole section is 418 bbls . ., Volume (4lculaltom



[8)

7-3


6. Use the Case> Hole Section Editor and change the Excess % to 15.00%. Hole Secbon Editor - -

--

Hole Name

j Hole Section

Hoje Section Deiith (MO)

j 200X10

Section Type

5900 12500.0 200'.Xl 0

I

P" Ackitional Cok.rM;

A

Meaoued Depth (A)

t±----- Riser J-_Casing i1- Open Hole II=

fmpott Hole Secl'IOl'I

Shoe

Length

Tapeied?

(ft)

ID

Mea$1.i'ed

fin)

Depth

__@_

r r 7500.oo r

59100 11910.00

Effeciive Hole

Drtt

rin1

Oiamelei

fin)

18.000 12500_0

12-375

12.250

12250

l.-r Capac(y (bbl/It)

Fncbon Factol

17.500 12.597

0.3147 01489 01541 l

0.20 0.20 O.:ll

Excess

Item Oescn1xoon

(%)

ASA Section. 20 in>< 18 in CAS 13 5.18 in, 8tt2 ppl, Q· 15.00 b H 12 1/2in

r

The total annular volume is 2, 118 bbls . ~

.., Volume C•lcut.tlom

The annular volume in the open hole section is 481 bbls .

fg)

.., Volume Calcul41ions ~ (<:Aoecty R4"9f) M)

MD(ft)

Top

VWne:s (bbO

I 12!i00

PO"

9413.t

e.. j 210000.o

IAm.M

I 13:-tJ.7

Jot41

I SJO 1• 1431. 11 : 1011 .es

~

I

~ SttflQJ o.oo

7. Use the Case> Hole Section Editor and set the Excess% back to zero.

Hole N-

!Hole Secllon

Hole SectM 0 <¢> (MDl

f:zoono Moa,..ed

SecilOnT)lle

Oeplh

lit)

AC-0 Open H°"'

7-4

IM'!>Ofl HoleSoction

I

:;; Addt10n41 Cokrms Length

1111

Shoe T~

MeM1'ed

10

Dril

Oe¢>

(111

fn)

Fnc:bon Footor

flt 18000

12500 0

12.375 12.250

1L250

17.500 12.250

0.20 0.20 0.30

03147

ASASeollorl.20nx18" 0 1 489~ CAS 135/lt ln. 98.2ppl. O· 0.1'581....-.....1!J&H 12 112 in




8. Use the Case> String Editor. This is the same string configuration used in the Running Liner case. St11ng Edi!cw Suing lnltlalizahon

_ _ _ _ _ __ Libraiy

Stting Nllllle jAttembly Stting [MO}

l2Cro10 Section Type

El
Sgeoly ITop to Bottom

Length (ft)

12250 00 600 7742.00 2.00

Meaiued Depth ft)

122500 12256 0 19998.0 20CXXl 0

3 OD

fril

5.000 12.000 9.625 9.625

lmpcMt String

I

10

fril

fmpcMt

weqy.

Item Oe;cnpbon

(pplJ

4.000 8.535 8.535 8.535

29 35 53.50 53.50 53.50

Oril Pipe 5 in, 25.60 pp/, S, 51n FH, 1 lJnef Hat'lgel 9 5/8 111, 53.5 pp/, Q·125. Tenam Blue Traonng 9.625 in. 53.5 pp/. 0 ·125

9. Use Case> Wellpath >Editor. Yes, this is the same wellpath used in the previous two designs

,_

...• .' ·" :'

r UI

tD



: 11

....

..

~

I

«' "

7-5


ff]@

IP Wellpath Options

r. sr.ewe...

r r r

MO Top r~

ReondOm Inc end Az

1

Rendom Inc~ Az

M~

r1

125000

0.50

2

None

T01tuo#y Penoo

flr9e Change Penoct

f500 0

ft

1~0

I\

lnterpalatm

H~

Define Cement Slurries and Spacers l 0. Specify the fluid data using the Case > Fluid Editor.

Review Pore Pressure and Fracture Gradient Data l l . Use Case> Pore Pressure. The maximum pore pressure of 13.5 ppg is at 13,253 ft TVD.

717 Hl 782 7!2 901

'" '"

851

8S2 8'0 906 931

947 !ts 104.2 1089 'la! 91l

94' 1005

106' 108S 1115 1115

1225 1275 1275 1325 1310

13 31

13• 13'2 1341>

7-6




12. Use Case> Fracture Gradient. The lowest fracture gradient of 14.75 ppg is at the prior shoe of 9493.8 ft TVD

2ll05

""

10683 1182'

1'310 211325

21317 21l188 2' 930 lOJOC 11828 32819

'.S49 )M.49 ~s

' :.'813

mu

USlS 51'4i 5'Jl8 61989 ~s

Review or Input Geothermal Gradient Data 13. Use Case> Geothermal Gradient. The BHST is 229.66° F.

Ip'

llJr8J

Geothermal Gradient

I

I

standard AddtW Plot Surface ~mbient

!:fudline: Temperature at Wei TVD

r T~ature@ 1132437 r.

Gradiert

fl

022966 ii

r;:so- ·F/1 Wt

Cancel



7-7


Review or Input Circulating System Data 14. Use Case> Cement Circulating System. The displacement volume is 0.34 bbls.

@[gl

'P Cement Circulating System

P

Use 51Mface Iron

Length

1100.00

It

Height from P~ to KB

125.0

ft

Diametei

11.870

in

Nl.rnber Linei in Paralel

11

!Displacement VoUT.e

10.34

Friction F11etoi

11.00

VokJme Per Stroke

12.100

OK

7-8

I ~~

bbjl gal/slk

Help

_j




Centralizer Placement 15. Use Parameter> Centralizer Placement. • CM:Uole Sl4nd
r-\

F\.odl'lot• ("' Ai Top f'luo Lando

Q Top al Cerbabd Interval

112500 0 ft 5P4C"lll Uroll ( B - Centr"'-'l

MO

StandollAbovelop~ •:

• 0...-.g M..i CondliotW'!I Wel>oreFlid~ I ~~~~~~::=:J~

Spacll'ig

It fD
r

r

Speca1lhe.ucv•11..mg ,_!ho tufaoe

°"""to TO

I""'~ cxdef

r

(ft)

r r

r

10.00

"""'whet> 111")1 •e ion l'itl lhe hole I

Torquo Drag~ (c-ig RurYW'911)

COl>)l 10 s~ Oevtee$'

C4'c Slei> Srze

J1000 00

ft

Speed Q

T•'l'P"!l !n

isoo- IVmn 1;)

0..:1<1.oot St* Hooklood al TO With Standalf OeYUS lncUlod

Exclded Ma.

r.._

Mn Hool
~

U'l

~ 10 ~lo 111•JO~

~ 1>1

iso:o- ~.o

Ma.. Hookload ~ ~

10000

:J

~ 15000

2

@IMO

l21nno

@MD

f0

@IMO : ~ 00

~

•O

50

55

60

65

70

Standoff ('lb)

"



7-9


Specify Depths of Interest 16. Access Parameter > Additional Data. For Reservoir Zone, enter the MD of Lhe well at TD (20,000 ft) and for Fracture Zone, enter the casing shoe depth ( 12,500 ft). You entered these depths because the MD of the well at TD has the highest pore pressure in the open hole, and the casing shoe depth has the lowest fracture gradient in the open hole. You can enter any depths of interest for these zones (weak zones or abnormal pressure zones not necessarily at prior shoe depth or well depth), if desired.

rI)IBJ

IP Additional Data

,750.0 Off*'<>re lnlosmation

r

Rett.ms at Sea Floor

ppg

Sea WtJ.er Density DeplM ol lnlerest IOI Plots/ Gas Flow Potential

Gas Flow Potenlial (last smJationJ

200ll0

ft

12500.0

ft

111 02

Temperab..re lrYOI~ BHCT

r.

r r

Calc:UateAPI BHCT

BHCT

1208.30

·F

Surface Temperat1.1e

110.00

•F

Mud Outlet Temperat1.1e

173.60

·F

12.2966

•F

BHST

OK

7-10

Edit Pictile

Tempeiature Profile

Csicel

Help

J




Estimate Bottomhole Circulating Temperature 17. Access the Hydraulics module by clicking the Y1' toolbar icon, and use the Mode pull -down list to access the Pressure: Pump Rate Fixed analysis mode. 18. Use Parameter > Rate to specify this information.

Quick Look

Pump Data

lii!i>~R= ate=:------:1= 400. ::::0=:=:~illlJ"""'"

Stand Pipe Prenure

1176812

psi

Mamiun S1.1face f'lessure

j7500.00

PSI

Surface E. Press1.1eLoss: 1100 00

Mal
12.00l.OO

hp

Bt Pressure Loss:

10.06

p$I

Bit Impact Force:

~

lbf

Bit Hjldlalltc Power

1001

hp

Percent Power at Bit.

%

HSI:

looo [o.o

B~ Nozzle Vekx:«y:

122

Maxm.m~PumpRale:

.-----

ljl?ITI

Obtain from Cilculating System I

,--lrl

Options

Annulus

r

in

Use Roughness

f.J Include Tool Joint PrOSSl.fe Losses

r

Include Back Preuure Back PresS1.te:

psi

~Mud Tempe1at.1.1e Effects

l___2_ime of CirWation: js.oo r

Pump Rate:

f4000

gpm

Returm at Sea Floor Sea \l./atei Density

r r

I

hi

hpfri'

- - ft/;

.,.

Total B~ Flow Area(Local) ,...I- - -

psi

I

ppg

Include CtAtingi Loading Ure Stlrng Editor BiNozzles

.___o_K_ _C«i_ce_t ~



_ _ __.I _ Help

J

7-11


19. Access View> Plot> Geothermal Gradient. Click the Data Reader icon to determine the temperatures, or click the Grid Vie w toolbar icon ( ['.J I) to view the data in tabular form. The annular surface temperature is 75.23° F. StTrig

Me.>st.1edO

0.0 5910 600.0 600.0 700.0 8000 900.0 100'.l.0 1100.0 1200.0 1300.0 1400.0 1500.0 1600.0 1700.0

70.18 70.62 71.16 n .77 12n

00 222.2 444.4 666.7 888.9 11111 1333.3 1555.6 1777.8 200)0

7170 74.75 75.87 77.~

78.26 79.54

76 43 77.58

78.79 80.30 81.84 8343 85.05

86.70

2222-2

00.86

8a38 90.c.3 91 .00 93.55 95.31

2444.4 2660.7 28889 3111.1

8223

83.64 85.10

0.0 222.2 444.4 666.7 888.9 11111 1333.3 1555.6 1777.8 2000.0 2222.2 2444.4 2666.7 2888.9 31 111

75.23

-ro

The annular bottomhole temperature is 208.5° F.

StTng fl 7712.4 7912.4 8112.4 8312.4 8512.4 871 2.4 891 2.4 9112.4 9312.4 951 2.4 9712.4 9912.4 10112.4 10312.4 1051 2.4 1071 2.4 10912.4 11112.4 11312.4 11512.4 1171 2.4 11912.4 121 12.4

7-12

Atnllar

Meas..edO

182.30 184.18 186.00 187.77 189.50 191.17 192. 79 194.35 19565 197.29 198.66 199.96 201.19 202.34 20141 204.39

205.28

200.06 206.75 207.32 207.78 208.12 200.30

fl 15111.1 15333.3 15555.6 15777.8 16000.0 16222.2 16444.4 16666.7 16888.9 17111.1 17333.3 17555$ 17777.8 1800).0 182'22.2 18444.4 18666.7 1eaaa.s 19111.1 19333.3 19555.6 19777.8 200XJ.O

M~edO

187.87 189.57 191.22 19282 194.36 195.85 197 29 198.65 199.96 201.19 202.35 203.43 204.42 205.33 206.14 206.85 207.46

207.SS 208.32 208.57 208,68 208.65

208:50 I



ft

1511 1.1 153313 15555.6 15777.8 l &XXJ 0 16222.2 16444.4 16666.7 16SS8.9 17111.1 173313 17555.6 17777,8 1800).0 18222.2 18444.4 19666.7 1B8S8.S 191 111 193333 19555.6 19777 8

20000 0


Input Cement Job Data 20. Activate the OptiCem module by clicking the OptiCem toolbar icon ( El j). Select Wellbore Simulator from the Mode pulldown list.

21. Use Parameter > Additional Data. Select the BHCT option. -

1p1

-

-

(1)(RJ

Additional Data

Rig Capaciy

175110

p- Rig Capacity

kip

Offshole lnlormation

r

Ren.m at Sea Floof

Sea 'Watei Density

ppg

Depth$ ol lnteiest For Plots I Gas Flow Potenbal Rese1Voi Zone (MD)

j2WXlO

ft

Fracture Zone (MD)

112500.0

ft

Gas Flow Potenbal (last sm.ilabon) 111.02 Tempeialue Information

r.

BHCT

r

CalculateAPI BHCT

I

Tempeialure Profile

BHCT

Ed~

j200.30

Piolile 'F

Surface T~eiature

jro.oo

'F

Mud Outlet Temperah.re

j73.60

'F

BHST

1229.66

'F

OK

Cancel



H~

7-13

Chapter 7: Cemen ting the Liner Solution

22. Use Parameter >Job Data. a. 5.66 bbls of shoe track is predicted. Job Dela IMef Sbng

r used

_J New Stage? Stage Nol

~

"Sboke

Method

Rate (bblll!Wl)

r

1 2 3 4-1

Vol.me Voll.me Top of Fluid Top of Fluid

10.00 10.00 10.00 7 00

140.00

4 -2

Shutdown

~S~/FkJsh 14. 0!JP9S~. 14.00p ~

"'

5

11 8 ppg DBM. 13.80 PP!;~

6

Volume Volume

10.00 10.00

200.00 200 00

t= J---_, ~ ~ ~

Twe

Flld

DrilngFld (Mu 13.BppgOBM, 13.80PP!;!'7 Spacet/F\Jsh 14.0 ppg Spac;e1, 14.00 p r.; Cement 14.5 ppg Lead. 14.50 PP!; IV Cement 16. 4 ppg T~. 16 40 ppg IV Cement 16. 4 llP9 Tai. 16 40 PPll Topf\Jg•

~Mud

r

ti--

Rate (spm)

Ouretion Volume (l!Wl) (bbl)

200.00 200.00 20000

Topol

Buk

fud Length -stroke$ (Measure (It)

Cemett

d Depth) 0.0 00 11848.3 1000.0 11848.3 401 7 6423 8 12250.0 5750.0 2344 5 180000 20000

000 5.00 3212 1675 5.00

0.00 50.00 32119 11722

1.00 n.32

200.0 19778 7 141 3 10.00 0.0 19778.7 72317 14463.3

<

l Back Pre.sue (psi]

14.70

"""Return Volume

0.00

Shoe Track Length Shoe Track Volume

7-14

J

p$1

• Top Plug or &!Mt al ospiacement •Entel volume per stroke on Cement Crculatrlg Sl'$lem diaog to use strokes - The last retuin volume rrust be 0 to~ that tin is the prew.ire lor the r~ al the Job .--~umallQQ..awog.c""""1W1JL.&Cwa:nu>.p1i"""ILW!la''9 (N~e opply to Anr..iW. Positive~ to String) Shoe Track

lao.o !sss

It bbl

p

Topf\Jg

Adcilional Pre.sue to S~ Plug j350.00



(941:> sack-s)

1325.99

46678

>


b. 1,326 sacks of lead cement, and 467 of tail cement are predicted. Job Data

r

-------

AIAomabc Rate Adiu;tment

SaletyF~

r Use Foam SchedoJe

r

r-

psi

New Stage? StaoeN

r

AnnWs Injection

Plocemeflt Method

Dtir.g Fld (Mu 13.8 ppg OBM. 13.80 ~ 17 Spacei/Flush 14.0 ppg Spacer, 14.00 p r;; Cement 14.Sppg l ead, 14.50~17 Cement 16.4 PP!I Tail. 16. 40 PP!I 17 Cement 16 4 ppg Tail. 1640ppg r

1 2 3 4·1 4.2

VoU!>e VoU!le

Top Plug' r;; Space
5 6

VoU!le

r

r u;ed

,ELod Edto!

Oi$4ble A1Ao-01$!llacement ~

Fluid

Twe

lmerStnng

Rate (bbl/mri)

Topol Flud Topol FUd

-Snoke Rate Duation Valme "'SIIok (mri) [bblJ (spm)

lllOO 10.00 10.00 7.00

140.00

10.00 10.00

20000 200.00

0.00 5.00 32.12 16 75 5.00

200.00 20000

20000

Studown

Vok.me

1 00

n.32

000 5000 32119 11722

Topol Fluid (MeasUt dD

Length (ft)

Bi.lo: Cement (941b sack.s

00 00 11848.3 1cm.o 118483 401 7 64238 12250.0 5750.0 23«.5 18000.0 200l.O

moo 200.0 19778 7 141 3 723.17 144633 0.0 19778.7

< ~sl

14.70

psi

BackPtessueRecped

•Top Plug 01 st!llt ol ~ • Enlei Yobi1e pei stroke on Cement C.cWllng S.Y$1em cialog to use strokes ·• The last return vdune mu1I be 0 to :qv/~ Iha! ltvs ri lhe pressure for lhe remande< ol tne !Cb ·-Estimation during Reverse CMcJatioti to prevef'll U~
0.00

Shoe Traci<. Length Shoe Track VoUlle

p Top Plug

It bbl

l80o

[5:66

Addtronal PtesNe to Seat Plug j350.00

c. Approximately 23 sacks would be required. Set the shoe track length back to 80 ft after checking. Job Data

r

AIAomatic RateAdjusbnent

Salety Factoo

r

Use Foam Schedule

r

lnne< Sbiog

r- - - psi

r used

Ellid E
Oi$able AIAo-O~emert !Aculation r Arroiu,I~ New Stage? S~N

Fil.Id 13.8 PP9 OBM. 13.80 PP9 14.0 WI! Spacei. 14.00 ppg 14.5 IJll9 Lead. 14,50 ppg 16.4 PP9 hi. 16 40 ppg 16.4 PP!I h i. 16.40 PP!I

1 2

3 4· 1 4·2

Plocemenl

Rate

Method

(bbl/1'111'1)

Vcbne

10.00

Valme

io.oo

Top ol Flid Top ol Flid Si'
10.00

5 6

7.00

-Sboke

Rate [spm)

Buk

Topol

Duration Valme FUd (nWI} (bbl} " St1okei (Me~

L~

(It}

d0e¢i)

200.00 200.00 200.00 140.00

sacks)

0.0 0.0 11848.3 1000 0 11848.3 401 .7 6423.8 12250.0 5750.0 2457.7 18000.0 2000.0

10.00 10.00

CelTlenl (9'1b

1325.99 48932

141.3 10.00 200.0 19698.7 717.50 14350J 0.0 19698.7

> Back Pressure (1>$1)

14.70

-Eil Back Ptessue Requied

0.00

J

psi

' Top ~ or st111t ol dispb::emer~ •• Ente< vobne per woke on Cement Ciculatiog System ciaio9 to use $llok'" '° The lau return Vok.ne nmt be 0 to sq.;ly tlW ttOs it !he pie$SU1e tne remai'>der ol the job · - E;tmation durn;i Re•em• CAC
'°'

Snoe Track Length

i1so.o

ft

p

Shoe Track Volume

111 32

bbl

Addibonal P1e$$Ule to Seat~



TopF\Jg

1350.oo

7-15


23. Use Parameter> Job Data. The displacement volume includes the cumulative volume of fluid s after the plug is dropped. 10 bbls (spacer) + 723. 17 bbls (mud) = 733.1 7 bbls. Job Data l~Strrig

r usec1

r

_J

Use Foam Schedule l~

F1uod

New Stage? Stage N~

r.1---- Orillng Ad (Mu 13.8 ppg 08M. 13.80 PP!: p~

Spacer/Flusn 14.0ppgSpacer, 14.00p p~ Cement 14.5 ppg Lead. 14.50 PP!: p~ Cement 16.4 ppg Tail 16.40 ppg pCement 16. 4 ppg Tal, 16 40 ppg lop~ P" Specer/fbh 14.0 ppg Spacef. 14 00 p p~Mud 13.8ppgOBM. 1 3.SO~p-

t?---..g_ J--

r

r2---

-Suoke

Placement

Rate

Method

(bWll'll'l)

1 2 3 4-1 4 ·2

Volume Volurne

5 6

Volurne Volurne

Top of Fii.id Top ol Fluid

Rate

l'll"'l

10.00 1Cl00 10.00 7.00

200.00 20000 20000 140.00

10.00 1Cl00

200.00 200.00

DuratJOn (ml'l)

Voll.me (bbij

Top of Flud

""Stroke~ (Measure

BlA<. Cement

Lengtn (ft]

(94b sacks)

dDepdi)

000 500 32.12 1675 5.00

Shutdown

0.00 50.00 32119 117.22

00 00 11848.3 1000.0 118483 401 7 6423 B 12250.0 57500 2344 5 1800) 0 20000

1 .~ 2000 m 11 14463 3

12

132599 466 78

141.3 19778.7 00 19778 7

r

<

>

J Back Pre""e (psil

14.70

"""'Est. Back Prem.re Requwed • Top Plug or sta
Snoe Trad< Lengttl

IEll.o

It

~Top Plug

Snoe Track Volume

[5.66

bOI

Addlional Pressure to Seat Plug jJS0.00

24. Use Tools > Volume Calculations to determine the pipe volume. The volumes are not equal because of the 5.66 bbls shoe track volume.

IBJ

!JI Volume Calculations Depths(CapecityRange)

Top Base

7- 16

MO (~)

T\IO (ft)

I o.o 121XOl.O

j 13243.7

\I~

Pipe

1738 .83

Total

['279
Between strinQS

!o.oo

o_.o___ ~

_I

J2L65. 55

=1 :..J



Convert

J

~

1


r ui..r

s~

r

1000 10G>

~00

:iooao

100 n32

1000

m11

MO 197187 1'13 1W>33 oo 1gna1

>

(

" Tco f'l.g t:1 !bit d d:;ilacmitN .. Cl'ttf~I* ur1C-1C.Cl#no - n,. ..... ftfVn ~ :i ti. o1o1 PT11

-r

~'

•

llm'lt kil.,..

ci1 "'r;0

llWtal~R·...cs.Uaua'l'OPf~
"GI

St.o. T'-"



7-17


Analyze Results Review Circulating Pressures 25. Use View> Plot> Circ Pressure and Density - Frac Zone. Hint Use the right-cli ck menu to view pressure vs. vol ume.

No, there is not a problem. The circulating pressures do not exceed the fracture gradient at this depth for the entire job.

7300

7200

7100 ~

·u; .9: Q)

::;; 7000 (l'J (l'J

Q)

Q_ 6900

6700 -300

-200

· 100

0

100

200

300

400

500

600

700

800

900

1000

1100

1200

1300

Volume In (bbl)

26. Use View> Plot> Circ Pressure and Density - Reservoir Zone. Hint Use the right-click menu to view pressure vs. volume.

)

7- 18




No, there is not a problem because the circulating and hydrostatic pressures do not fall below the pore pressure at TD during the entire job. ~·c~Pre~U1ea!Reservor_;:::one

__________ _

_

__ _ __

_

10300 10200

10100 10000

-B Vi

~

::::i

(/) (/)

9900 9800

Q) ~

0..

9700 9600 9500 9400 9300 0

100

200

300

400

500

600

700

800

900

1000

1100

1200

Volume In (bbl)



7-19


Review Downhole Pressure Profiles 27. Access the View> Plot> Downhole Pressure Profiles plot.

2000

4000 6000

g

LEGE N D

- - MexSl\um ECO o PorePr~e

16000

-4.- Fradure Gradient ~ Mirimum Hydrostatic GrO
18000

,____,___......_ __....

20000 7.00

7.50

8.00

8.50

9.00

9.50

10.00

10.50 11 00 11.50 12.00

12.50

13.00 13.50

14.00

14.50 15.00

ECO (ppg)

a. Use this plot for a quick overall picture to determine if you will have well control or ECD issues at any depth in the open hole. b. No, because the maximum ECD and minimum hydrostatic gradient curves lie between the pore pressure and fracture gradient curves. c. The hydrostatic gradient curve represents the minimum gradient at any given time that could be present in the annulus. d. This curve represents the maximum ECDs that can be anticipated at various depths.

7-20




Review Density and Hydrostatic Profiles 28. The Density curve represents the static density of each flu id at the end of the job. The Hydrostatic Gradient curve represents the cumulative hydrostatic gradient of all fluids in the wellbore at the end of the job. fonalD~n~lly~Hydf~~JCf'l_Qlile _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __

LEOENO

4000 6000

14000 16000 18000 20000 7

a

9

10

11

12

13

14

15

16

Density I Hydrostatic Gradient (ppg)



7-21


Compare Rates In and Out 29. Use the right-click menu to view Rates vs. Time.

0

100

200

300

400

500

600

700

soo

900

1000

1100

1200

1300

Volume (bbl)

a. This plot displays the total annular return rate and corresponding pump rates versus the fluid pumped into the well (a comparison of the volume of material pumped in with the volume coming out of the well). The difference between the two rate curves indicates free fall. If free fall occurs and the well goes on vacuum, the rate out will initially exceed and then fall below the planned pumped rate. b. There is slight free-fall at the start of displacement during the job. c. The free-fall does not appear to be severe enough. The predicted rates (in and out) are about the same for most of the job. d. This is for foam jobs when both liquid and gas phases are present. However, it is not applicable in this design.

7-22




Review Wellhead and Surface Pressures 30. Access View> Plot> Calculated Wellhead/Surface Pressure. ~alculatNlSiifacePr<'i~ ure

_ _

_______

2000

_ __

LEGEND - - CabAaled Wehad Pressure o calculaled Pump Pressure

1500

500

0

100

200

300

400

500

60 0

700

800

900

1000

11 00

1200

Volume In (bbl)

a. The maximum calculated wellhead surface pressure is 2,017 psi, and occurs at the end of the job when the plug is bumped. b. The pump pressure is at the cement unit ; the wellhead pressure is at the wellhead. c. The maximum pump pressure is approximately 2,277 psi. d. After the heavier fluids move to the annulus, additional pressure is required to lift these fluids up the a nnulus.



7-23


Review Hookloads 31. Access View > Plot > Hook Load Simulation. Hook ~olld Smulation {Effective Pipe Weight n Temtt ol Hool, load vs VokJme lnj

0

100

200

300

400

500

-~---

600

700

800

900

1 000

11 00

1 200

Volume In (bbl)

a. No, the predicted hookloads during the entire job are well above the neutral buoyancy. b. No, the rig capacity is not exceeded. The calculated hookloads

are below rig capacity during the entire job.

7-24




c. C li ck the ~ I icon to remove the lines of interest from a plot. Immediately after free-fall occurs, the displacement fluid catches up with the tail slurry.

420 415 410

405

0:

'5Z. :;;- 400 ID 0 ....J ~

0 0

395

I

390 385 380

0

100

200

300

400

500

600

700

800

900

1 000

11 00

1 20 0

Volume In (bbl)

Use the Fluid Animation to Analyze Job Parameters 32. Access View >Animation > Fluid Positions. a. Right-click the plot to access the Fluid Positions Frame Animation Properties dialog box. Uncheck all the check boxes associated wi th labels, and check the 1/2 Cutaway check box.

cg:]

,,., Animation Properli"s label>

r

si- Depth Reference

r r

si- eesaiptions

Options

r

r

Cancel

~Oellths

~-__;

1/~Cut-.w

rv' l /


7-25


b.

Staoo No

I

138ppg08M

2 3

14 0 PPO Spac"

V.U..ln

Tlm01n Strol<""* SLrfac:e Preuue

frac Zone ~enie

14SPPOLead 164pegT..i 1'0pegSPdC"

lliOO" bbl ~[00

rii63 96

"" ""

~729

Res.ZonePi..,..e

fm,.~p..

Raleln

r;ooo-

Ra100o.t

~blil-

OltOUl!ll Oe¢i

t!llC»OftArtUI>

Rate

1000

bW!IW'I

Pi......

93113 70

pa

Ea>

~Pl>o

VolAvg.ApplltontV- 4l>n

cp

D....ay

f13"iJ

POii

a~

f~

t



blilrM

.i]

o.,.., flale

7-26

,.

FUdName


c . Refer to the colo r legend in the upper right corner of the animation. PodrftzFr"llll!

_ _ _

__ _

_

__ _

_

________

V,._I"

__

bbl

000

io:oo """

hnef"

s.....

roo-~116396

""

Fite. Zone Ptet'M'e

[63l72!1

""

R., Z....Pl......e

l976A 67

""

Rat•

riooo--riooo--

s..1-Pl-..e

i;.,.a.. O°""H°'"

.-.-.~ .. O~l

O[C6""9\ Oop1h

J1900l0hAtn.M

R~e

finOO

blll/mn

Pl......

i""170

pa

ECO

fH 17 -

01>11

Vol A"ll Appoc...Vaooofy 46

f n-

CO

o~

[11eo

01>11

Quelly

rm- \

I I

d . Click the ~ butron to begin the animation. 488 bbls have been pumped when free fall occurs. You can tell when free fall begins because the color indicator (black) for free fa ll appears. Hint Use the VCR buttons to stop, start, and step through the simulation.



7-27


138PP!IOBM

UOPP!IS145PP!IL~

16 4 PP!1 Tail

140PPOS-

"""""'" r ... 1n

197683

s..tacef'lem.
Zone Pteuue

!000

pa

6894 20

""

Rate In

ls72565- pa 'ooo-bbll....

RdeOul

~bbl/....

Rei Zone Pte.1aue

O°"'"Hole

Of~

fi9CXJO 0 ft ArnAn

ROie

6 "i3

bbl/,,..,

p,......

934i114

P•

ECO

~

pog

Oenuy

7-28

13111

PP!I

o~

.ooo

Hydo°"""°G•o6oni

j0n7

HdeOedned

flOOZAa.pd



O~tl

Oo¢>

1: p1il'H


e. . •,

Stoge No

1 2 3

'

5

FUdN.,,,.,

138ppg08M 14 0 Rl9 s 1'5Rl!IL-i 16•Rl!IT..14DppgS-

VoUneln

488 41

bbl

hnoln

'54.00

l1WI

S~o1;.,

1976113

SUlfacePr....,o

rooo-

PSI

F1ao Zeno Pressu-e

61194 20-

PD

Rei- Zone PrelSl.60

[97256>

pv

Rote In

R""'OIA 0_,Holo

O(AttU.")

O(C""'I:]

Oep1ti

R.te

~

l190000n~

rsn-

bbl/Im

9348 14

P'J

1412

Vol Avg. App.sent V-•y SS 67

f.

ppg cp

Oen>i:y

13il

Owity

1DOO

H)'
~""'11

Hole Cleaned

l 1om:~

ppg

:t

Finish the simulation.



7-29


g. 132 minutes .

.

•,

Stooe

FUdN..,..

No

f±------1'- - ~

r.--.--J

138ppg08M 140ppgS145ppgl.Md 164ppgT• l40ppgSllO«ll

J 1122192

VoU!ieln

bbl

~-

[ Tmoln

1MJ84 !<01"""737 [6827 i6

S1r~e:

Sui..,.Pteuuro frac. Zone Pt9J.1Ule

375063

R., Zone Pt.....,e

""

!000 ro:oo

Rate In Ra1e01.t

""

"" bbl/mm bbl/mm

Down Hole

) OtC-01 l>«>ch

O~l

-

h9l00 0 ~ AnrWs

Rate

000

f'testl.le

j9324 fiT

ECD

~ ppg

""

VolAV!I Al>J>sentV...,,..iy l~oo

cp

o.....i,JI

PPO

Quaity

1640

inoo- \

Hyctoitatic Gr.oent

l~pso/ft

Holeci-led

j100XA~

h. To properly design the optimal thickening times for the slurries.

7-30




Review Hole Cleaning 33. Use the Parameter> Analysis Data dialog box. Check the Erodibility and Eccentricity check boxes. Select the Enter Top/ Bottom MD radio button and specify the depths. Click OK and the simulation will run.

!pf

Analysl~ Oat~-

-

-- - - - - - -

-

- rlJIBJ

P° Eccerircly ~ Ero
IReqcired Shear Stum (lll/100ft2) o::J

120.00

I 5% T~at\.fe Range at Midpoint

Top MD

j1acxxw

ft

r. Enter Top/Sottom MD

MidpontMO

I

rt

Bottom MD

j2COOJ.O

rt

Depths

I Entie Open Hole Section

SimulatOI Step Size

P Calculate Automatically Votme Increment

I

bbl

OK

Cancel

Apply

J

Help

J

34. T he tail slurry section is predicted to be fully cleaned with 100% mud removal.

2000

4000

6000

g

~

0

'O

~

8000

10000

:>

"'~

12000

~

14 000

16000

18000

95.00 95.50 9800 96.50

9700 9750 99.00 9850

9900 99.50 100.00 10050 101.00 101.50 102.00 102.50 103.00 10350 10 4.00 10450

Hole Cleaned(%)



7-31


35. Analyze the entire open section in the annulus. a. Access the Analysis Data dialog box and select the Entire Ope Hole Section radio button. Click OK to re-run the calculation:

rl)rg]

Analysis Data

1p1

P Eccenlricity

P

ErOObility Mud Erodibity (W'elbole Fluid)

IRequired Shear Stien (lbl/1Wt2) iJ

j20.oo Depths

r

~Temperature Range al Midpoint

Top MO

r

Entet Top/Bottom MO

Midpoint MD

rt

Bottom MD

ft

r. Erne Open Hole Sectoo

ft

SirnUator Step Size

P

U!iculate Automabcally

Voll.rnelncrement

I

bbl

I

7-32

OK

I_

Cancel

Apply

j_



Help

j


b. Access View > Plot > Erodibility Profile. There is mud cake remaining. There is an increase in mud cake between the previous shoe and l5,000 fl because this interval does not have centralizers. Er

_ryProlie

_

_

__

_

_

_

_

__ __

___

_ _ __ _

_ __

0 2000 4000 6000

g £

a. (])

0 "O

8000 10000

~

:::J If)

(1) (])

12000

2 14000 16000 18000

--I

20000 60

65

70

75

BO

85

90

95

100

Hole Cleaned (%)

c. Ideally, I 00% mud removal is desirable for the entire cemented section. In this exercise, only a good tail placement was required and the tail section is I 00% clean. In the centralized interval

containing the lead slurry, there is a small (less than 3%) mud cake. If the design required the entire cemented section to be cleaned, the following changes could be made to the design: -

A mud with a higher erodibil ity number could be used.

-

Centralizer placement could be improved over a longer interval. Specially formulated spacers (for example, tuned spacers) that achieve higher mud removal could be used. Non-conventional cementing techniques (for example, foamed cement) cou ld be used.

d. Fluid tops and ECDs may be affected by remaining mud cake.



7-33


Fine-tune the Job Re-examine ECDs and Fluid Tops 36. Access the View > Plot > Downhole Pressure Profile plot. Notice the increase in ECDs. The increase in ECDs is most likely to cause a problem at TD. POWllfiolePtew..v~PtoH~

_ _ _

_

_

_

_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __

2000

6000

g

LEGEND - - Maxilwl'I ECO

16000

O PcrePre~e --&- Frecllxe Gradieri

~ MirlrTun Hyd'oslllbc Grediert

18000

7.00

7.50

8.00

8.50

9.00

9.50

10.00

10.50

11 00

11 .50

12-00 12.50

13.00

13.50

ECO (ppg)

7-34



14.00 14.50 15.00


37. Use the Parameter > Additional Data dialog box. Click OK to close it and re-ru n the simulator to update the results.

Rog~

p

1750.0

RogCapaciy

Offshofe lnlotmation

r

Aell.Ins at Sea Flool

Sea Wa1.e1 Deml\jl Depths o( lntere~t foi Plots I Gas Flow Potential ReseNOf Zeno (MD)

1200000

ft

Fract1.1eZone (MD)

1200000

ft

Gas Flow Potential (!Mt sm.Aal.oo)

11 22

Tempe1at1.1e lnlotmaloo ~ BHCT

(" Cak:UateAPI BHCT

Edit f>lo(ile

(" T~all.le Pldile BHCT

1200 :.>

SI.Iface Tempei ah.re

110.00

'f

Mud 01&1 Tempe1al.1.1e

17360

'F

229.66

BHST

OK

Cancel



Apply

'F

'f Help

7-35


38. Access View > Plot > Circulating Pressure and Density Fracture Zone (in volume). Notice the c irculati ng pressure is very close to the fracture zone toward the e nd of the displacement at TD. C•~f'lniureelFreu<1eZone

_ _

_

___ ___

_ _

_

_____ _ _ __ _ __

10300 10200 10100 10000

·u; ~ Q) ....

9900

ril Ul

9800

0.

9700

Q)

....

9600 9500 9400 9300 0

100

200

300

400

500

600

700

800

900

1000

Volume In (bbl)

7-36



1100

1200


39. To add a safety factor, use the Parameter> Job Data dialog box to select Automatic Rate Adjustment with a I 50 psi safety factor. Job Da!a

_

IP

htomatic RateAdju$1ment Sdety F!1Cto1

r Use Foam SchedtJe

T~

r

1150.00

~

_ _ _

NStage? StageN

rud

Eluod Editor

14.0ppgSpacer. 14JXlp ~ 14.Sppglead, 14.SOPP!;r.>' 16.4 ppg Tai. 16.40ppg ~ 1s.4ppght 1s.4oppg r

Top Plug" rv Spacer/Posh 14.0 ppg Spacer. 14_00 p w Mud 13.8 ppg OBM. 13.BO PP!; p-

Placement Method

_

_

_ __ _ _ _ __

lmerString rused

J

Dtsable hto-Oisplacement ~ r Al'Y"otlknl~

Drlng Fld [Mu 118 ppg OBM. 13 80 PP!;~

Spacer/Flwn Cement Cement Cement

_

Rate (bbllmin)

""S~oke

Rate (spm)

1 2 3 4·1 4· 2

Valme Valme Top of Fluid lop oll'Ud St.Jtdown

10.00 10.00 10.00 7.00

200.00 200.00 200.00 140.00

5 6

Vobne Vobne

10.00 10.00

200.00 200.00

8\A(

Topol

Duratoon Valme (roo)

000 5_00 3212 16 75 5.00 1.00

n32

r

(bbl)

000 50_00 32119 117 22

""Stick

o_o

Fluid

Len¢\ (ft)

(Me4SUI

dD

l

00 11848 3 1000.0 11848.3 401 7 6423.8 12250.0 57500 2344.5 18000.0 2Cm0

Cement (941> sacks)

1325.99 466.78

10.00 200.0 19778.7 141 .3 723.17 144633 0.0 19778 7

<

> --•Est Bl!Ok Pressure ReQU11ed

Beck Ptessure (psi) 14.70

o_oo

r-

J

PSI

•Top Plug or start ol ~ - Entei l/Olurne pei itroke on Cement Circuialll'l!l System Oalog to U$e strokes ·-The last return l/Olurne rrust be 0 to sq.fJt that this it the ixeuure for tne remamder ol the iob ~~ Estmalion durll'l!l Aevene Ciculation to prevent U·lubing (Negairve ~ to.Amulls. PO$ilve applji to Stmg) Shoe Track

Shoe Track Len¢l Shoe Trl!Ok VolurTie

leo.o

11

~bbl



p

Top F\Jg

AddiboM Pressure to Seat Plug f350.00

7-37


40. Access View > Plot> Circulating Pressure and Density Fracture Zone. Notice the circulating pressure is no longer near the fracture gradient because the rates have been adjusted toward the end of the job. Note the safety factor region has been added to the plot. Crcul~".19£'1e1sureatF1ach.•eZone

_ __

__

_

_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ___ _ _ _ _ _ _ _ _

10300 10200 10100 10000 ·u;

.e, ~

:::J

ti) ti)

9900 9800

Q)

a::

9700

-

9600 9500 9400

-g -+---"..,.~'+l'.'::lE- ~ ~,9281..f!lpSl,--13.SQ.ppg.(20000.Q.tt}-

9300 0

100

200

300

400

500

600

700

800

900

1000

Volume In (bbl)

7-38



1100

1200


4 1. Access View >Plot> Comparison of Rates In and Out. Notice the rates dropped near the end of cement job. Approximately the last 50 bbls are pumped at the slower rate of 5 bpm instead of the planned l 0 bpm. ~ioon ol

Rate In and Out [Total Anrulat Return Ade Md the Coue:pondong Pump A~te vs Volrne lnJ

10

5

9

4

B

3 2

c:

~ .0

6

2co

s~-~--+--+--+~~---~---~..,._,~-

e..

er: -0

·:; 4

er

~

3

-2

2

-3

0

1 00

200

300

400

500

600

700

800

900

1000

11 00

1200

1300

Volume (bbl)



7-39


42. Access View > Plot > Downhole Pressure Profiles. Notice the decrease in ECO as a result of the reduced flow rates. !)~Pre>st.r~Protje _ : _______

__

_ _ _ _ _ _ _ __ __ ___

____

___ _

2000 4000 6000

14000 LE G END

16000

----- Maxirurn ECO

o

Pore Pre$$U"e

- - f raclu'e Oredieril ~ Mnmum Hydrostatic Gfadient

18000

7.00

7.50

8.00

8.50

9.00

9.50

10 00

10.50

11.00

11.50

12.00

12.50

13.00 13.50

14.00

ECO (ppg)

7-40



14.50

15.00


43. Access View> Animation> Fluid Positions. Fast forward to the end of the simu lation. S-...icO!i>Ona Op00n

lroScale

.

~~~~~~~~~J V~ln

11221.92

T~ln

1136:11

s~-

12••38'

... bbl

s..iacePr....,,.

ji21837

POI

F1ac:Z....,Pr..,..o

f9766.39

Res Zona Pret11.a:e

1976639

""

AA In

fo.oo

R«eO"

""

W/mon

moo-

bbl/mon

OownH•

O~J

O(c:-.gj

D

1!nnO nArnin

Roto

000

P1e-nur.e

1§3.i'["•l

-

bW""'1

""

W,-Vol Avo Aopot...tVISCO>ly 9999SOO cp ECO

Den"y Q"""y H)
Hole Cleaned

16.
-

ro:oo- ~

'a732- - pWI, iiiiJ 00 ~ Colc:tkred

a. The red denotes the section where the mud was not fully removed. Use the Erodibility plot to determine the percentage of mud remaining. b. Place the mouse pointer over the top of the lead slurry in the animation schematic to view the predicted top of the lead slurry.



7-41


It is 11,947 ft (compared to the previous 12,250 ft) . Fl uid tops are also reported in the Wellbore Simulator report.

St
Fluodll..,,.

1

1

2 3

3

4

138Pll!IOBM UOPll!IS°"""' 1'5Pll!lu...d 164Pll!llai

5

5

UOppgS_..

2

•

I

V.._ln

fffiigr-bl>I

fmeln

lm.23 f2«38.

..,

J202592 1976639

""

F'1;,c. Zone PtetNe

z..,..p,.,...,.

f97i;"a39

s11oi-

S11loc:ePreu11e Aei.

jOOO

""bl>l/mn

RoteOOJI

'Ooo

bl>l/mn

.

O(C-o)

'1!1lOOOll-

Ao!•

[(ioo

Piel-wre

j3340.0

ECO

!1• 11

Oemity

bW"""

""

W9

cp

J16~ l>l'O

Qwlly

fOOO

"

H!40
[0.732

pU/11

H... Oeoned

flOO.oox c.w.tect



OIAIYkMJ

O
Vol.AY!l ~\/~c:oo«)I 19999900

7-42

""

Aoto ln

Oowni-lcie

J


c.

I• I

Place the mouse pointer over the top of the spacer in the animation schematic to view the predicted top of the spacer. It is l 0,812 ft versus the planned l l ,848 ft. ----

Schemooc Op0on: Option jToSC
-

--

- - - - -

-

- - - - - - -

138PP!IOBM HOPP!!S...14 5PP!lleod 164PP!IT..i IHlPP!!Spacet

) Voi
1

1221 92

bbl

13223

f1Wl

Strait..

124"384

Suf&ce PtesS\.fe

120a92

PSI

Free. Zone Ptec:M.ae

""

ResZooePr......,o

[9761>39 J9766 39

Ra1efn

f[OO

bbl/l!WI

Ro!eO._.

JO:oo

bbl/mn

pol

o_,Holo

OIC-.Ol Oei>(h

OIArn.ml

J l !mlOft~

Rae

jU.00- bWmn

Prenue

193-4043

pso

ECO

pm

PP11

va..Avg. Awarent V-v fssmoo

<1>

o~

J1s 40

PPll

Q~v

~t

HjiO'O>ta!Je G1.oe.-.

JO}J2--

Holea.-d

1100.00 ~ed

P
If the annular volume is significantly filled with non-mobile mud, it will increase the velocity and frictional pressure losses elevating the ECDs. Also, this can cause fluid tops to be higher than anticipated. It is a good

practice to review all parameters if mud displacement efficiency is not 100%.



7-43


7-44



Wellplan Training 2

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