WellPlan Exercie Book

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WELLPLAN

Exercise Book

2003.5.0.2 (EDM 2003.5.0.2 (03.13.03))

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WELLPLAN Exercise Overview

The exercises in this book are designed to familiarize you with

WELLPLAN. All of the exercises analyze a single well, however not all exercises analyze the same hole section. You will analyze running and cementing an 11 3/4” liner. You will also analyze drilling the 14 3/4” hole section which is drilled after setting the liner. This well has a weak zone that complicates much of the design.

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 exercise, you will create a new pipe grade and then use this pipe grade 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

This exercise builds on the previous two exercises. Using the data hierarchy created in Exercise 1, you will specify additional data that defines the case you are analyzing. You will use the information you entered into the catalog in Exercise 2 as well as use the catalog you imported.

At the end of this exercise, you will import an xml transfer file that contains data you will be analyzing during the rest of the course. The data you import is very similar to what you specified in the previous exercises. In order to ensure that all course participants have the same data for the rest of the exercises, an xml file is imported.

Exercise 4: Using Torque Drag Analysis

During this exercise, you will become familiar with using the Torque Drag module. You will analyze drilling the 14.75” hole section. You will use Drag Charts to quickly look for trouble areas. You will follow this analysis with the Normal Analysis for a more in depth investigation of certain areas.

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Exercise 5: Using Hydraulics Analysis

During this exercise, you will use the Hydraulics module to determine the minimum flowrate to clean the 14.75” hole section. You will also determine the maximum flowrate to avoid turbulent flow, and optimize bit hydraulics. You will also determine the tripping schedule, and predict ECD while tripping.

Exercise 6: Using Well Control Analysis

In this exercise, you continue to analyze the 14.75” hole section. You predict the type of kick to expect given certain circumstances. You estimate the volume of the influx and the pressure to expect given the size of the influx. The kick tolerance is investigated and a kill sheet is prepared.

Exercise 7: Using Surge Analysis

This exercise examines the surge and swab pressures to expect while running the 11 3/4” liner. The exercise also examines tripping and reciprocating the 12 1/4” BHA in the 14 3/4” hole section.

Exercise 8: Using Cementing - OptiCem

This exercise analyzes cementing the 11 3/4” liner. Circulating and wellhead pressure are investigated, in particularly near the fracture zone.

Exercise 9: Using Critical Speed Analysis

This exercise examines a range of rotating speeds while drilling the 14 3/4” hole section to determine which speeds may result in damaging vibrations.

Exercise 10: Using Bottom Hole Assembly Analysis

This exercise predicts the behavior of the 12 1/4” BHA while drilling the 14 3/4” hole section.

Exercise 11: Using Stuck Pipe Analysis

Using the Stuck Pipe Analysis module, you will determine the loads required to set, trip, and reset the jar. You will determine the load required to backoff at a specified measured depth, as well as the load that will fail the string.

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Exercise 12: Using Notebook

You will review the analysis options available within the Notebook module.

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Exercise 1: Creating the Data Hierarchy

1. Launch WELLPLAN (Start > Programs > Landmark EDM >

WELLPLAN).

2. Enter EDM as the User ID and landmark as the Password on the login screen.

3. Create a new company. Using the Well Explorer, right-click on “EDM 2003.5db” and select New Company from the menu. 4. Specify Company properties.

a) Using the Company Properties > General tab, rename the company Class.

5. Create a new project when prompted or by using File > New >

Project.

a) Use the Project Properties > General tab to specify project properties. Name the project Kananga. Use Mean Seal Level as the System Datum.

6. Create a new site when prompted by clicking the Yes button. a) Use the Site Properties > General tab to specify general site

information. Name the site Largo North Platform. The Default

Site Elevation is 114.8 feet above MSL. Use Grid as the North Reference. Do not apply a tight group. (Use Unrestricted.)

7. Create a new well when prompted by clicking the Yes button. a) Use the Well Properties > General tab to specify general well

information. Name the well LPN-004. Use API units and no

Tight Group. Leave other tab fields blank.

b) Use the Well Properties > Depth Reference tab to specify the well depth reference, configuration (offshore or onshore), and to view a depiction of the datum. Create a datum titled DFE with a

114.8 ft elevation. This datum is the default datum. (Check the Default box.) The rig name is Scorpion 100. This is an offshore

well in 328.1 ft of water. Specify an 84.8 ft wellhead elevation. 8. Create a new wellbore when prompted.

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a) Use the Wellbore Properties > General tab to define general information about the wellbore. Name the wellbore ST1. 9. Create a design for wellbore ST1. Name the design P1. Use DFE @

114.8 ft (Scorpion 100) as the depth reference. This well is a

sidetrack from wellbore 1. WELLPLAN isn’t concerned with tie-on information. Case > Wellpath Editor defines the wellpath that will be used for analysis. Other Landmark Drilling Software use

sidetrack data. Because the data used in WELLPLAN training is also used for training of other software products that are concerned with tie-on information, this well is labeled ST1.

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Exercise 2: Specifying Tubular Properties, and

Working With Catalogs

1. Create a pipe grade named VMHCQ-125. This grade has the following properties:

• Section Type: Casing/Tubing • Material: CS API 5CT

• Minimum Yield Strength: 125 kpsi • Fatigue Endurance Limit: 25,000 psi • UTS: 135 kpsi

2. Create a new Casing/Tubing Catalog with a name of your choice. 3. In the new casing/tubing catalog, create another pipe with the

following properties: • Nominal Diameter: 11 3/4” • Nominal Weight: 65 lbs • Grade: VMHCQ-125 • Body OD: 11.75” • Body ID: 10.682 in • Weight: 65 lbs. • Pipe Type: Special • Drift ID: 10.625 in • Internal Yield: 9,940 psi • Collapse Resistance: 6,540 psi • Body Yield Strength: 2,352,010 lbf

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• Linear Capacity: 0.1108 bbl/ft

• Closed End Displacement: 0.1341 bbl/ft • Average Joint Length: 40.0 ft

• Wall Thickness: 87.5 % • Plain End Cost: leave blank

4. Make a new Units set and name it ‘Class’. (Tools > Unit System) Base the new unit set on API units. In the Class unit set, make the following changes. Notice that the active Unit Set name is

displayed in the bottom right corner of the Main Window. The active Unit Set is saved with the Case.

a) Use the unit ‘psi/ft’ for Mud Weight.

b) Has the unit for density changed? (Case > Fluid Editor) c) Activate the API unit set. (Tools > Unit System.)

5. Import a catalog of diverter subs using the file DS Catalog.xml. To import the catalog, highlight Catalogs in the Well Explorer and then right-click. Select Import from the right-click menu. Review the information in the catalog. Diverter subs will be used in the Surge exercise.

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Exercise 3: Using the Case Menu

1. Define the hole section, including the last casing, liner, and the open hole section. (Case > Hole Section Editor) The well depth is 17,968 ft. Use 12,534 ft of 13 5/8”, 88.2 lb/ft, Q-125 casing with 17.5” effective hole diameter. Enter the 11 3/4”, 65 ppf, VMHCQ-125 liner. (You entered this in the last exercise.) Use Casing as the section type for liners. The effective hole diameter is 14.75. There is 1,837 ft of 12 1/4” open hole. Use .2 friction factor in cased hole and .3 in open hole. The open hole is gauge.

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

> String Editor.

• String Depth: 17,968 ft

• Drill Pipe: 12,589.24 ft, DP 5 in, 19.50 ppf, G, NC50(XH), P • Heavy Weight: 60 ft, HW Grant Prideco, 5 in, 49.7 ppf

• Jar: 28 ft, JHM Bowen Hyd/Mech. 6 3/4” OD, 2.5” ID (Note: Adjust the jar length to 28 ft.)

• Heavy Weight: 300 ft, HW Grant Prideco, 5 in, 49.7 ppf • Drill Collar: DC, 390 ft, 8” X 2.5”, 7 H-90

• Stabilizer: 5 ft, IBS, 10 5/8” FG, 8 X 2.5” • Drill Collar: DC, 390 ft, 8” X 2.5”, 7 H-90 • Stabilizer: 5 ft, IBS, 10 5/8” FG, 8 X 2.5”

• Drill Collar (Non-mag): 31 ft, NDC 8” X 2.5”, 7 H-90 • Stabilizer: 5 ft, IBS, 10 5/8” FG, 8 X 2.5”

• MWD: 30 ft, MWD 8, 8 x 2.5 in • Mud Motor: 30 ft, BHM 8, 8 x 2.5 in • Sub: 3 ft, BS 6, 6 x 2 1/2 in

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3. Import the wellpath data. Use File > Import > Wellpath Data to import the file WP2003_5TrainingWellpath.TXT. Your instructor will tell you where the file is. The column order and units are: MD (ft), Inc (deg), and AZ (deg). (Note: It is important that you

correctly specify column order and units.) Review the wellpath data using Case > Deviation > Wellpath Editor.

4. Enter mud properties on the Fluid Editor. Click the New button to enter data for a new fluid. (Case > Fluid Editor). After you are finished inputting fluid properties, click the Activate button to indicate you want this fluid used in the analysis. Use the following properties:

• Name: 15.1 ppg OBM • Density: 15.1 ppg • Type: Non Spacer • Base Type: Oil

• PV: 24 cp at 120 degrees F • YP: 7 lbf/100ft2 at 120 degrees F • Rheological Model: Power Law

a) What are the calculated Fann dial readings?

5. Copy all pore pressure and fracture pressure from the file

WPPoreFrac.xls. (Copy over all data (if any) already present in the

pore pressure and fracture pressure spreadsheets.) Use CTRL-C and CTRL-V to copy and paste the data. In Excel, highlight all columns and then copy. In WELLPLAN, highlight the first row and use CTRL-V to paste the data.

6. Specify the geothermal gradient. The surface ambient temperature is 80 degree F, the mudline temperature is 40 degrees F, and the temperature at TD is 279.5 degrees F. What is the geothermal gradient?

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

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pressure loss is 100 psi. Define three pumps. Activate the 12-P-160 pump.

8. Create the following tabs (View > Tabs) by renaming or creating additional tabs. Use window splitters near the scrollbars to create window panes.

a) Create a tab titled Schematic. On that tab, create two vertical panes containing a Well Schematic-Full String and BHA-Not

to Scale schematics. (One schematic in each pane.) Turn the

header off in the Full String schematic.

b) Create a tab titled Editors. Create two horizontal panes on that tab. Open the Hole Section Editor in one pane and String

Editor in the other pane.

c) Create a tab titled Deviation. Create two vertical panes. Open the

Wellpath Editor in this tab.

d) Create a tab titled Plots. Open the Inclination plot in this tab. 9. This exercise step demonstrates the Freeze Line. (Later in this

course, this feature will be applied to more meaningful sensitivity analysis.)

a) Using the Plot tab created in the previous step, place the cursor (arrow) on the data curve of the Inclination plot. Click the right mouse button, and select Freeze Line. Specify the color of the freeze line to be green and change the name of the curve. b) Using the Deviation tab, change the inclination near 2527 ft to

50 deg. Notice the two curves visible at 2,527 ft on the

Inclination plot.

c) Using the right mouse button, click on the previously frozen line. Select Hide Line. What happened to the line?

Name Vol/stk (gal/stk) Max speed (spm) Max Discharge Pressure (psi) Horse Power (hp) 9-P-100 3.685 150 2790 900 10-P-130 3.984 140 3595 1170 12-P-160 6.433 120 3200 1440

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d) Add a background logo to the plot. Right-click anywhere on the plot. Select the Background tab. Click the Bitmap button. Add the Halliburton logo to the plot. Your instructor can tell you the location of the file.

e) Close the plot.

10. Generate a survey Vertical Section plot. (View Wellpath Plots

Vertical Section) Use the window splitters to give this plot the

entire workspace on the Deviation tab.

11. Change the width of the data curve on this plot to 3. (Hint: Right-click on the curve and use right-Right-click menu.)

12. Activate the Graphics Toolbar by clicking anywhere on the plot. 13. Use the Data Reader (third button from left on Graphics Toolbar)

to determine the vertical section at TD. What is it?

14. Click on the Data Spreadsheet button (fourth button from the left on the Graphics Toolbar) to view X/Y coordinate data for the plot. Click the Arrow button (left button on Graphics Toolbar) to return to the plot view.

15. Click on the Properties button (right button on Graphics Toolbar) to open the Properties tabs. The following questions highlight the functionality of these tabs. (Hints: To easily view the changes to the plot, move the Properties tabs dialog box so that the plot is visible. Don’t forget to click the Apply button 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.

f) Using the Legend tab, turn off the legend. 16. Save this case.

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17. Export this Case at the Company level using the filename of your choice.

18. Import the data file WELLPLANTraining2003_5.xml. This transfer file contains data you will be analyzing during this training course. For the rest of the course, you will be using the well LPN-004, wellbore ST1 in the site Kananga of the Full Feature Oil Co. company. This well is exactly like the one you just finished creating. To ensure that everyone has the same data, we are using the imported data rather than the data you entered.

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Exercise 4: Using Torque Drag Analysis

Steps and Questions

1. Open the case titled TDA 14 3/4” Hole Section

2. Activate the Torque Drag Analysis module and select Drag Chart analysis mode.

3. Copy the assembly for the 12 1/4” Hole Section case in the well

LPN-0042, wellbore ST1 plan P1 to the 14 3/4” Hole Section case.

Change the string depth to 17,968 ft.

4. Review the hole section information and make a note of the open hole section measured depth interval. (Case > Hole Section) 5. Activate the 15.1 ppg OBM. (Case > Fluid Editor)

6. Open the template torquedrag.tpt. Review the different tabs. (File >

Workspace > Open Template)

7. Apply tortuosity to the interval below 4,680 ft. This well is actually a sidetrack of another well. Tortuosity should only be applied to planned wellpath data. It should never be applied to actual survey data. In this example, there is actual survey data above 4,680 ft. Use the Random Inc Dependent Az method. Apply 0.30 between 4,680 ft and 7,000 ft. Below 7,000 ft, apply 0.50 degrees. Use a 100 ft Angle Change Period and interpolate every 30 ft. Review the tortured wellpath data to observe the revised inclinations. 8. Specify 50 kips traveling assembly weight. Include bending stress

magnification (check the box), use 31 ft as the contact force

normalization length, and analyze all mechanical limitations (again, check associated boxes). (Case > Torque Drag Setup)

9. Analyze the open hole interval (16,131 - 17968 ft) every 100 ft. Use 20 kip WOB and 2000 ft-lbf torque at bit for rotating on bottom operation. Also analysis rotating off bottom, and both tripping in and out. There is no rotation while tripping. (Parameter

> Run Parameters)

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a) What does the Tension Point chart tell you? (View > Plot >

Tension Point Chart or access the Drag Tension Point Chart

tab)

b) What does the Torque Point Chart tell you? (View > Plot >

Torque Point Chart or access the Drag Torque Chart tab)

c) What is the minimum WOB to avoid helical buckling while rotating on bottom? (View > Plot > Minimum WOB Chart or access the Drag Min WOB tab) Does the Drag Chart tell you where the string is buckling? If not, how could you find out where it is buckling?

11. Access the Normal Analysis mode. When using the Normal Analysis mode, where is the bit assumed to be?

12. Determine if buckling or fatigue is likely to occur for any selected operation mode. (View > Table > Summary Loads or click the

Summary Load tab)

13. Where does the buckling occur while rotating on bottom? (View >

Table > Load Data > Rotating On Bottom or click the Load/Stress Data tab)

14. Where is fatigue or tensile yield likely to occur:

a) While tripping out? (View > Table > Load Data > Tripping

Out)

b) While rotation on bottom? (View > Table > Load Data >

Rotating On Bottom)

c) While rotating off bottom? (View > Table > Load Data >

Rotating Off Bottom)

15. How could we solve the fatigue and yield problems in the string? Try adding a 8050 ft section of S grade, 19.5 ppf drill pipe near the surface. Does that remove the yield or fatigue prediction?

16. If fatigue is still a problem, try using a different class or a different weight of S grade pipe near the surface.

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Answers

1. Double-click on the case name in the Well Explorer to open it. 2. Click the Torque Drag toolbar button, or use the Modules menu. 3. Using the Associated Data Viewer, right-click on the assembly you

want to copy and select Copy from the menu. In the Well Explorer, highlight the case you want to copy the assembly to, right-click, and select Paste from the menu.

4. Use Case > Hole Section. The open hole interval is between 16, 131 and 17, 968 ft MD

5. Using Case > Fluid Editor, click once on the desired fluid to highlight it, then click the Activate button. Notice the tear drop next to the fluid indicating it is the active fluid.

6. Use File > Workspace > Open Template. 7. Use Case > Deviation > Wellpath Options.

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10. Does the Drag Chart analysis predict any problems in this interval? a) Use View > Plot > Tension Point Chart or access the Drag

Tension Point Chart tab

During a tripping in operation when the bit is at 17,431 ft the string is very close to buckling. Notice that this chart does not tell us anything about buckling while rotating.

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b) Use View > Plot > Torque Point Chart or access the Drag

Torque Chart tab.

This plot does not indicate that torque is going to be a problem over this interval. Notice that the make-up torque is always greater than any expected torque while rotating.

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c) Use View > Plot > Minimum WOB Chart or access the Drag

Min WOB tab. Does the Drag Chart tell you where the string is

buckling? If not, how could you find out where it is buckling?

11. Access the Normal Analysis mode using the Mode drop-down list. The bit is assumed to be at the string depth indicated on the Case >

String Editor spreadsheet.

Over the interval analyzed, we can determine from this plot that the minimum WOB to avoid buckling varies from slightly over 0 kips to slightly less than 10 kips WOB. We know we must be buckled, because we specified 20 kips WOB in the analysis parameters. To determine where it is buckling, you must use the Normal Analysis mode.

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12. Use View > Table > Summary Loads or click the Summary Load tab.

13. Use View > Table > Load Data > Rotating On Bottom. Notice that buckling occurs near the bit. Scroll down the table and notice there is also fatigue and yield problems further up the string.

14. Where is fatigue or tensile yield likely to occur:

a) While tripping out, there are problems from the surface to 3,740 ft MD. Use View > Table > Load Data > Tripping Out. b) While rotating on bottom, there are yield and fatigue issues from

3,000 - 4,400 ft and also around 650 ft MD. Use View > Table

> Load Data > Rotating On Bottom.

c) While rotating off bottom, there are problems off and on from surface to 7,500 ft MD. Use View > Table > Load Data >

Rotating Off Bottom.

Using this table, we can see there are a variety of problems including pipe yield, fatigue, failure, and buckling. Refer to the online help for a definition of codes.

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15. Adding a 8,050 ft section of S grade, P, 19.5 ppf drill pipe near the surface resolved some, but not all of the problems.

16. Using 25.6 ppf, first class pipe solves the problem.

17. If the buckling near the bit is still a problem, you could reduce the WOB. You probably won’t get rid of all the buckling.

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Exercise 5: Using Hydraulics Analysis

Steps and Questions

1. Open the Case HYD 14 3/4” Hole Section 2. Open the workspace template hyd_template.tpt.

3. Select the Hydraulics application, and Hole Cleaning -

Operational from the Modules menu, or click the Hydraulics

button and select Hole Cleaning - Operational from the Mode drop-down list.

4. The pressure response data for the mud motor in the current work string is 350 psi loss at 530 gpm and 350 psi loss at 900 gpm. Add this to the mud motor description.

5. Set the string depth to 17,968 ft to put the bit “on-bottom”. (Case

String Editor)

6. What are the bit nozzle sizes? (Case String Editor) 7. Use the Circulating System dialog to answer the following

questions, or to perform the following steps. (Case Circulating

System)

a) What is the maximum working pressure specified? (Case

Circulating System Surface Equipment tab)

b) Specify surface pressure loss of 100 psi.

c) Mark the pump name 12-P-160 the active pump. (Case

Circulating System Mud Pumps tab)

8. Specify the cuttings transport analysis parameters. (Parameter >

Transport Analysis Data)

• ROP: 25 ft/hr

• Rotary Speed: 90 rpm • Pump Rate: 400 gpm

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• Cuttings Diameter: 0.125 in • Cuttings Density: 2.500 sg • Bed Porosity: 36.00 %

• MD Calculation Interval: 100 ft

9. Determine the minimum flow rate required to clean the wellbore. (View > Plot > Operational)

10. What is the percentage of cuttings suspended compared to the total volume of cuttings?

11. Change the yield point to 15 lbf/100 ft 2. Did this impact the required minimum flow rate and the bed height?

12. Determine the maximum flow rate. Analyze every 25 gpm between 400 and 600 gpm. Use the Annular Velocity Analysis. (Modules

Hydraulics Annular Velocity) (Parameter Rates) Answer the

following questions pertaining to this analysis.

a) Use the Annular Velocity (View Plot Annular Velocity) plot to determine which flow rates result in non-laminar flow, and where does this flow regime occur?

b) What is the critical annular pump rate inside the casing? What is the critical annular velocity inside the liner? (View Plot

Annular Pump Rate)

13. Select the Pressure: Pump Rate Range (Modules Hydraulics

Pressure: Pump Rate Range) analysis mode.

a) Analyze flow rates between 400 gpm to 600 gpm in 25 gpm increments. Default Pumping Constraints from the Pump Data. Include tool joint pressure losses. (Parameter Rates)

b) Specify ECD calculations to be performed at the casing shoe (16,132 ft) and at TD (17,968 ft). (Parameter ECD Depths) c) How is the maximum pump pressure calculated when it is

defaulted from the pump data and there is more than one active pump? (Hint: Use the online help.)

d) Generate a Pressure Loss report.(View Report Pressure

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down the inside of the drill pipe? (Hint: You can not read this directly.) Is there turbulence in the annulus at this flow rate? Record the bit, string, and annular pressure losses.

e) Generate a Pressure Loss plot. (View Plot Pressure Loss) Use the Data Reader to determine the bit, string and annular pressure losses at 425 gpm. Compare these values against those in the Pressure Loss report. Do they match?

14. Perform Optimization Planning analysis to optimize bit hydraulics. (Modules Hydraulics Optimization Planning)

a) Select the Opti Plan tab.

b) Specify the analysis parameters. Default pump data. Specify a minimum nozzle size of 10/32nds and specify that 8 nozzles be used. Allow 60% pressure loss at the bit. Specify 80 ft/min as the minimum annular velocity. Include tool joint pressure losses, and do not allow turbulent flow in the annulus. (Parameter

Solution Constraints.)

c) What is the pump rate and nozzle sizes to maximize bit hydraulics if we want an HSI between 2 and 6?

d) Close the Solution Constraints dialog.

15. Will the pump rate determined in the previous step clean the hole? 16. Can we pump at this pump rate using the nozzle sizes identified?

Use Pressure: Pump Rate Range analysis and refer to the View >

Plot > Pressure Loss plot.

17. We need to increase the pump pressure. Leave the current Pressure Loss plot open. Activate the 10-P-130 pump in addition to the 12-P-160 pump. Did this help? Why or why not? (Hint: Refer to online help.)

18. De-activate the 10-P-130 pump. Change the liner size on the 12-P-160 pump. Use a 5.5” liner size with a maximum discharge pressure of 5000 psi and 3.702 gal vol/stk. Now can we pump at the required pump rate to optimize hydraulics?

19. Perform a Swab/Surge Tripping Schedule (Modules

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a) Analyze closed and open end for both surge and swab scenarios. Use 523 gpm for the flow rate for the open ended swab and surge analysis. Use a 90 ft stand length and .5 ppg delta P. Use local nozzles (8X10). (Parameter Operations Data)

b) Generate a Swab/Surge (View Report Swab/Surge) report. For the closed end swab scenario, how fast can the first few stands be tripped without causing a change greater than 0.5 ppg? 20. Perform a Swab/Surge Pressure and ECD analysis using the same

data as in the previous step. Generate a Swab Closed End plot (View Plot Swab Closed End). What is the ECD at the casing shoe for a 50 sec/stand trip speed?

Answers

1. Open the Case HYD 14 3/4” Hole Section by double-clicking on it in the Well Explorer.

2. Open the workspace template hyd_template.tpt. Use File >

Workspace > Open Template.

3. Select the Hydraulics application, and Hole Cleaning -

Operational from the Modules menu, or click the Hydraulics

button to select the Hydraulics application, and select Hole

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4. Use Case > String Editor. Highlight the row associated with the mud motor. Use String > Data to add the mud motor data.

5. Use Case String Editor.

6. Use Case String Editor.

7. Use the Circulating System dialog to answer the following questions, or to perform the following steps. (Case Circulating

System)

Set the string depth to 17,968 ft to put the bit “on-bottom”.

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a) What is the maximum working pressure specified? Use Case

Circulating System Surface Equipment tab.

b) Specify surface pressure loss of 100 psi.

c) Use Case Circulating System Mud Pumps tab. Maximum working pressure

Check the Active box to make the pump the active pump.

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8. Specify the cuttings transport analysis parameters using Parameter

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9. Determine the minimum flow rate required to clean the wellbore using View > Plot > Operational. Use the Data Reader to read the minimum flowrate.

10. The percentage of cuttings suspended is less that one percent compared to the total volume of cuttings, which is almost 6.5%.

Notice there is a bed height of

approximately 1.5” when the flowrate is 400 gpm.

The minimum flowrate to avoid a cuttings bed is 451.7 gpm.

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11. Use the Case > Fluid Editor to change the yield point to 15 lbf/100 ft 2. Yes, this reduced the required minimum flow rate and the predicted bed height.

12. To determine the maximum flow rate, use the Annular Velocity

Analysis. Use Parameter Rates to specify range of flowrates to

analyze.

a) Use the Annular Velocity (View Plot Annular Velocity) plot to determine which flow rates result in non-laminar flow. In Minimum flowrate

required using adjusted yield point.

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this example, turbulent flow occurs somewhere between 525 and 550 gpm.

This plot displays the annular velocity in each section of the well for each flowrate specified on the Rates dialog.

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b) What is the critical annular pump rate inside the casing? What is the critical annular velocity inside the liner? Use View Plot

Annular Pump Rate.

13. Select the Pressure: Pump Rate Range (Modules Hydraulics

Pressure: Pump Rate Range) analysis mode.

Critical pump rate in the 13 5/8” casing is 667 gpm.

Critical pump rate in the 11 3/4” liner is 532.7 gpm.

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a) Analyze flow rates between 400 gpm to 600 gpm in 25 gpm increments. Default Pumping Constraints from the Pump Data. Include tool joint pressure losses. (Parameter Rates)

b) Specify ECD calculations to be performed at the casing shoe (16,132 ft) and at TD (17,968 ft). (Parameter ECD Depths) c) If you have more than one active pump specified on the

Circulating System/Mud Pumps tab, the Maximum Pump Pressure will be set equal to the minimum value entered for Maximum Discharge Pressure for any of the active pumps. d) Generate a Pressure Loss report.(View Report Pressure

Loss) At 425 gpm, read the pressure loss inside the drillpipe.

Then divide this pressure loss by the total length of the drillpipe. Refer to Case > String Editor for the length of the drillpipe. There is no turbulence in the annulus. Refer to the Annulus section of the report.

e) Generate a Pressure Loss plot. (View Plot Pressure Loss) Use the Data Reader to determine the bit, string and annular pressure losses at 425 gpm. Yes, they match. Notice the bit pressure loss is low.

14. Perform Optimization Planning analysis to optimize bit hydraulics. (Modules Hydraulics Optimization Planning)

a) Because of the template you imported, the Opti Plan tab is already setup to include the Optimization Planning analysis dialog (Solution Constraints).

Click Default from Pump Data to use data from the pumps marked as active on the Case > Circulating System > Mud Pumps tab.

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b) Specify the analysis parameters. Default pump data. Specify a minimum nozzle size of 10/32nds and specify that 8 nozzles be used. Allow 60% pressure loss at the bit. Specify 80 ft/min as the minimum annular velocity. Include tool joint pressure losses, and do not allow turbulent flow in the annulus. (Parameter

Solution Constraints.)

c) A pump rate of 532.2 and nozzle sizes of 8 X 10/32nds is required to maximize bit hydraulics if we want an HSI between 2 and 6.

d) Close the Solution Constraints dialog.

15. Yes, this pump rate will clean the hole. We determined that 426 gpm is required for hole cleaning.

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16. Use Pressure: Pump Rate Range analysis and refer to the View >

Plot > Pressure Loss plot.

17. We need to increase the pump pressure. Leave the current Pressure Loss plot open. Activate the 10-P-130 pump in addition to the 12-P-160 pump. This doesn’t help because we are limited by the lesser pressure of the two active pumps.

18. De-activate the 10-P-130 pump. Change the liner size on the 12-P-160 pump. Use a 5.5” liner size with a maximum discharge pressure of 5000 psi and 3.702 gal vol/stk. Don’t forget to reselect the active

At 532 gpm, the system pressure loss is greater than the pressure the pump can produce. Therefore, we can’t p[ump at this rate using the pump we have active.

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pump information on the Parameter >Rates dialog by clicking the

Default from Pump Data button.

19. Perform a Swab/Surge Tripping Schedule (Modules

Hydraulics Swab/Surge Tripping Schedule) analysis.

a) Analyze closed and open end for both surge and swab scenarios. Use 523 gpm for the flow rate for the open ended swab and surge Add another row to indicate the

pump with the new liner size.

It is close. You probably want a to try another liner size.

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analysis. Use a 90 ft stand length. Use local nozzles. (Parameter Operations Data)

b) Generate a Swab/Surge (View Report Swab/Surge) report. For the closed end swab scenario, the first 101 stands can be tripped at 20 sec per stand.

20. Perform a Swab/Surge Pressure and ECD analysis using the same data as in the previous step. Generate a Swab Closed End plot

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(View Plot Swab Closed End). The ECD at the casing shoe for a 50 sec/stand trip speed is 15.01 ppg.

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Exercise 6: Using Well Control Analysis

Steps and Questions

1. Open the Case WCN 14 3/4” Hole Section.

2. Select the Well Control application, and Expected Influx Volume from the Modules menu, or click the Well Control button and select Expected Influx Volume from the Mode drop-down list. 3. Review the Geothermal Gradient.

4. Specify the use of the Steady-State Circulation Model for the well control analysis. (Parameter > Temperature Distribution) Specify a flow rate of 500 gpm and a flow line temperature of 104 degrees Fahrenheit. Click OK.

5. Generate a Temperature Distribution Plot. (View > Plot

Temperature Distribution) Answer the following questions.

a) Why does the geothermal gradient profile change slope? b) What do the annulus and string curves represent?

6. To determine the type of kick encountered, specify a Circulation Flowrate of 520 gpm and a Kick Interval Gradient of 0.80. (Parameter > Kick Class Determination) Click Apply and answer the following questions.

a) What type of kick would occur in this situation? Why?

b) What is the difference between the interval pressure where the kick occurred and the static BHP (psi)?

7. After the Kick Class has been determined, you can calculate the estimated influx volume.

a) Specify that the kick detection equipment is based on flowrate, and can detect a 40 gpm flowrate change. (Parameter > Influx

Volume Estimation > Kick Detection Method tab)

b) Specify the reservoir properties. The porosity of the reservoir is 25%, the permeability is 10 md, the reservoir thickness is 100 ft

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and the rate of penetration is 25 ft/hr. (Parameter > Influx

Volume Estimation > Reservoir tab)

c) Crew reaction times have been entered for you. What is the total crew reaction time specified from detection of kick up to and including closing the choke? This is modeling a “soft shut-in”. How could a “hard shut-in” be modeled? (Parameter > Influx

Volume Estimation > Reaction Times tab)

d) In this scenario, what size influx was predicted? (Parameter >

Influx Volume Estimation > Results tab)

e) Change the detectable flowrate variation to 20 gpm. Click

Apply to process the changes. Now what is the predicted influx

size?

8. Now that we know the expected influx volume, we will analyze the pressures associated with a kick of this size. Select Kick Tolerance from the Mode drop-down list. First, we must finish entering data required to define the current kick situation.

9. Use the Circulating System dialog (Case > Circulating System) to answer to following questions, or perform the following steps.

a) What is the maximum working pressure specified on the

Surface Equipment tab?

b) On the Mud Pumps tab, mark the pump name 12-P-160 with the 3.702 gal/stk volume the active pump.

c) Click OK to activate your changes and close the dialog. 10. Configure well control options. (Case > Well Control Setup)

Specify the BOP rating to be 10,000 psi, and the casing burst rating to be 6,540 psi. Use an 80% casing burst safety factor. We will be using the “Wait and Weight” method to kill the well. A leak off test was run with 15.1 lb mud. The leak off pressure was 1,900 psi. (Case > Well Control Setup Operational tab) Click Apply. 11. Use the Steady-State Circulation temperature model (Parameter

Temperature Distribution) to estimate the influx volume. The

flowline mud temperature is 104 degrees Fahrenheit, the flowrate is 500 gpm and the mud density is 15.1 ppg.

a) What flowrate is represented on this dialog? (Hint: Use the Help.)

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b) Click OK to activate your changes and close the dialog. 12. The Kick Class was determined earlier in this exercise while

estimating the influx volume. What Circulation Flowrate is entered (Parameter > Kick Class Determination) dialog? Is it the kill circulation rate?

13. Now we must specify information that will be used to simulate and analyze the results of circulating the influx. (Parameter > Kick

Tolerance) Assume a gas influx. Specify a kill rate of 130 gpm,

with a kill mud gradient of .55 psi/ft. We will be circulating a 14 bbl influx. We are interested in analyzing the situation at the casing shoe (16,131 ft). We are planning our next casing shoe at 17,968 ft. Click OK to accept your changes and close the dialog.

a) What is the correct interval to analyze if we want to check the next casing shoe depth of 17,968 ft?

14. Answer the following questions pertaining to the results of the Kick Tolerance analysis. All analysis results (plots and schematics) are available via the View menu.

a) Determine the maximum annular pressure to expect at the depth of interest. (View > Plot > Pressure at Depth) Use the data reader to determine the maximum pressure. What is the

maximum pressure? What volume of kill mud had been pumped when this pressure occurred? Why doesn’t the curve have a constant slope?

b) Click the right mouse button on the curve and select Freeze Line. (Click the arrow on the Graphics Toolbar to exit Data Reader mode.) Change the color of the curve to purple. Change the Legend description to “Max Pressure at Shoe”. Click OK. Do not close the plot.

c) Change the depth of interest to 17,000 ft. (Parameter > Kick

Tolerance) Determine the maximum pressure to expect at

17,000 ft as the kick is circulated out. (View > Plot > Pressure

at Depth) What is the maximum pressure? Can you still see the

curve line for the maximum pressure at 16,131 ft?

d) Determine the maximum pressure resulting from the specified influx volume.(View > Plot > Maximum Pressure) Will the casing shoe be able to withstand the maximum pressure resulting from this size of kick?

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e) Would the current casing shoe depth (16,131 ft) suffice if there was a full gas evacuation? (View > Plot > Full Evacuation to

Gas)

15. Much of the information required to generate a Kill Sheet can be entered prior to taking a kick. Select Kill Sheet from the Mode drop-down list. Enter the following information to be prepared if a kick should occur.

a) Generating a Kill Sheet requires input on the Well Control

Setup dialog. Much of this information was input earlier in this

exercise. However, slow pump data must also be entered. Please specify the following slow pump information.

b) Specify the use of pump 12-P-160 at 30 spm. Use the Select

Pump/Kill Speed button on the (Parameter > Kill Sheet, Pumps Tab). Click Apply.

c) Enter the string volume. Use the Default from Editors button (Parameter > Kill Sheet, String Tab). Click Apply. If a string was not entered on the String Editor, you would have to input this information yourself.

d) Enter the annulus volume. Use the Default from Editors button (Parameter > Kill Sheet, Annulus Tab). Click Apply. If a string and wellbore were not entered on the String Editor and the Hole Section Editor, you would have to input this

information yourself.

e) Specify information regarding weighting up the mud. (Parameter > Kill Sheet > Weight Up Tab) The mud tank volume is 800 bbls. Mixing capacity is assumed to be 50 lb/min. Barite is the weighting material used in this example. The specific gravity of barite is 4.2, and is available in 94 lb bags. Click Apply.

16. When a kick is taken, information regarding the kick must be entered on the Parameter > Kill Sheet > Kick Parameters Tab. For this exercise, assume a 25 bbl pit gain at 11,029 ft. The Shut-In Drill Pipe Pressure is 520 psi, the Shut-In Casing Pressure is

Pump Name Speed (spm) Pressure (psi)

12-P-160 30 400

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720 psi, the Overkill Pressure is 100 psi, and the Trip Margin is .5 ppg. Click OK to activate your entries and to close the dialog. 17. Use the Kill Sheet report or plot to answer the following questions.

a) How many sacks of weighting material will be required to weight up the mud?

b) Determine how many strokes are required to fill the string with kill mud? How many minutes will this take? (View > Report >

Kill Sheet)

c) Determine the standpipe pressure after the string is filled with kill mud. (View > Plot > Kill Sheet)

Answers

1. Double-click on the desired case within the Well Explorer to open it. 2. Click on the Well Control button to select the Well Control

module. Select Expected Influx Volume from the Mode drop-down list.

3. Use the Case > Geothermal Gradient tabs. 4.

Click the Steady State Circulation button to use that model.

You do not need to specify the mud density because it defaults from the Case > Fluid Editor.

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5.

a) The Geothermal Gradient profile changes slope because the plot is MD, not TVD.

b) The annulus and string curves represent the steady state circulating temperature in the annulus and the string. 6.

a) A kick while drilling would occur in this situation because the pore pressure is greater than the circulating BHP.

b) The difference between the interval pressure where the kick occurred and the static BHP is 274.2 psi.

The Quick Look section displays the results.

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7. Use the Parameter > Influx Volume Estimation tabs to determine the influx volume.

a)

b)

c) Total crew reaction time is 5.6 minutes. A “hard shut-in” could be modeled by setting some of the reaction times to zero. Use Parameter > Influx

Volume Estimation > Kick Detection Method tab to specify the kick detection equipment.

Use Parameter > Influx Volume Estimation > Reservoir tab to specify the kick detection equipment.

Add the reaction times to determine the total crew reaction time.

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d)

e)

8. Select Kick Tolerance from the Mode drop-down list. 9. Use the Case > Circulating System tabs.

a) 6000 psi

An 58.3 bbl influx is predicted.

A 14.0 bbl influx is predicted when the detection flowrate is reduced to 20 gpm.

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b)

10. Use the Case > Well Control Setup > Operational tab to configure some of the analysis options.

11.

Check this box to make the 12-P-160 with 3.702 gal/stk volume the active pump.

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a) The flow rate on this dialog is the average flow rate over the last 24 hours.

12.

13.

a) The depth interval to check to reach the casing shoe at 17,968 ft would be 1,837 ft. (17,968 - 16,131)

14.

a) The maximum pressure is 12,779.8 psi when 2 bbls have been pumped. The curve does not have a constant slope because it The circulation flowrate is

the flowrate during drilling just prior to taking the influx. It is not the circulation kill rate.

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reflects the changes in pressure resulting from changing fluid lengths in the different annular sections.

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c) The maximum pressure is 13,462 psi when 2 bbls have been pumped. Yes, you can still see the curve for 16,131 ft.

d)

Yes, the shoe can withstand the kick of 14 bbls.

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e)

15. Select Kill Sheet from the Mode drop-down list. a)

The casing shoe could not withstand a full evacuation to gas.

Use Case > Well Control Setup > Slow Pumps to specify slow pump information.

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b)

Click the Select

Pump/Kill Speed button to select the pump speed from the dialog that appears.

The Select Pump/Kill Speed dialog appears when the Select Pump/Kill Speed button is clicked.

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c)

d)

Click the Default from Editors button to use the data entered on the Case > String and Case > Hole Section editors.

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e)

16.

17. Use the View > Report > Kill Sheet report or the View > Plot >

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a) Use View > Report > Kill Sheet.

b)

c)

1486.6 sacks are required.

2147 strokes are required to fill the string. It will take 71.6 minutes.

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Exercise 7: Using Surge Analysis

Note

Because of class time constraints, we will not be using the low clearance option during the course because of the length of time required to perform the calculations when the low clearance option is used. However, you should consider using this option in the future. The low clearance analysis is an improved analysis model that tightly couples the fluid forces with the axial forces. This analysis option results in more reliable results, particularly when the clearance is less than 0.5 inches and/or the analysis interval is long. The low clearance analysis can take a considerable amount of time to calculate. Therefore, when you use this analysis option, it is recommended that you analyze one operation at a time, and that you limit the analysis to two moving pipe depths.

Steps and Questions

1. Open the Case SRG 11 3/4” Liner.

2. Click the Surge button to start the Surge module.

3. Assume the well has only one formation from the surface to TD. This formation has an Elastic Modulus of 1,500,000 and a Poisson’s Ratio of 0.3. (Case Formation Properties) 4. The cement set behind the casing has an Elastic Modulus of

3,000,000 and a Poisson’s Ratio of 0.35. (Case > Cement

Properties)

a) Why don’t you specify the cement properties using the Case >

Fluid Editor?

5. Use 13.35 ppg OBM. This mud has already been defined. There is no pumping while tripping.

6. Define a surge operation. Name it Run Liner.

• Specify Depths of Interest to be at 12,834 ft (casing shoe) and at 16,131 ft (TD). Will these depths of interest be used for all operations? You should also analyze any weak formations. Are there any you should consider?

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• Assume you want to analyze when the pipe is at the previous casing shoe (12,834 ft), and near TD (use 16,000 ft). You may also want to consider analyzing when the pipe is at the weak zone.

• To define analysis parameters for this operation, click on the row number for the operation titled Run Liner to highlight the row. Next, click the Details button.

• Enter a pipe stand length of 90 ft, pipe acceleration of 1 ft/sec2, and pipe deceleration of 1 ft/sec2. Do not use a float. Do not check the Optimize Trip Time box. Why don’t you need to enter a Maximum Trip Speed? (Parameter Operations Data

Details Button Analysis Conditions)

• Specify a pipe speed of 100 ft/min for cased hole and open hole. (Parameter Operations Data Details Button Analysis

Depths)

7. Is this operation likely to fracture the formation?

8. To avoid fracturing the formation, you may want to use different trip speeds. Determine the safe tripping speeds using Optimize

Trip Time. Use a maximum trip speed of 180 ft/min.

9. You may also want to consider using a diverter sub to avoid fracturing the weak zone. Uncheck the Optimize Trip Time box and add a divertor sub to the workstring. Use the diverter sub in the catalog that has the 0.589 flow area. Does the diverter sub reduce the surge pressure enough to avoid fracturing the weak zone? 10. Define a swab operation. Name it Pull Liner.

• Use the same moving pipe depths as you did for the surge analysis.

• Use the same depths of interest as you did for the surge analysis. • To define analysis parameters for this operation, click on the row number for the operation titled Pull Liner to highlight the row. Next, click the Details button.

• Enter a pipe stand length of 90 ft, pipe acceleration of 1 ft/sec2, and pipe deceleration of 1 ft/sec2. Use a float with zero percent open area. Do not check the Optimize Trip Time box. Why don’t you need to enter a Maximum Trip Speed? (Parameter

Operations Data Details Button Analysis Conditions)

• Specify a pipe speed of 60 ft/min for cased hole and open hole. (Parameter Operations Data Details Button Analysis

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11. Is this operation likely to cause a kick?

12. Assume the float has a 25% open area. Compare the results for depth of interest 16,131 ft with the float having 0% open area. To easily compare the results, use the Freeze Line feature. After you finish comparing results, right-click on the “frozen” lines and remove them.

13. After the 11 3/4” liner is cemented, is there any problems tripping in, tripping out, or reciprocating the 12 1/4” string used to drill the next hole section? Use the case 12 1/4” Tripping Ops. The surge and swab operations have been defined for you. Define a

reciprocation operation. Name it Reciprocate. (Parameter

Operations Data) To define analysis parameters for this operation,

click on the row number for the operation titled Reciprocate to highlight the row. Next, click the Details button.

a) Enter a pipe acceleration of 1 ft/sec2, and pipe deceleration of 1 ft/sec2. Do not check the Float Used in Workstring box. (Parameter Operations Data Details Button Analysis

Conditions)

b) Specify a Stroke Length of 31 ft, and a Stroke Rate of 5 spm. Use 15.1 ppg OBM with a Flow Rate of 400 gpm. (Parameter

Operations Data Details Button Reciprocation Data)

14. Is it likely that these operations will cause any problems over this drilling interval?

Answers

1. Double-click on the case you want to open in the Well Explorer. 2. Click on the Surge button to select the Surge module. 3.

Enter the formation properties based on true vertical depth (TVD). These data are used to calculate the compressibility of the formation.

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4.

a) Because the cement is already set. The Case > Cement

Properties dialog is used to specify the properties of set cement.

The Case > Fluid Editor is not.

5. Use Case > Fluid Editor to activate the 13.35 ppg WBM if necessary. There is no need to use the Parameter > Job Data dialog because there is no pumping while tripping.

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6. Determine the weak zone by referring to Case > Fracture

Gradient.

Notice the weak zone at 13,253 ft vertical depth (not measured depth).

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Define a surge operation using Parameter > Operations Data.

• Use Parameter Operations Data Details Button

Analysis Conditions.

• Use Parameter Operations Data Details Button

Analysis Depths.

Highlight the row and then click Details to input details about the operation.

You don’t need to specify the last casing shoe or TD as a Depth of Interest because they are automatically added.

You don’t need to specify a maximum trip speed because you are not optimizing trip times.

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a) Analysis Depths default from the moving pipe depths specified on the Surge Operations Data dialog.

7. Use View > Single Operation Plot > Transient Response Plot. Use Data Selection to view the results at the weak zone.

8. Check the Optimize Trip Time box on the Analysis Details tab to indicate you want to have WELLPLAN determine the trip speeds to avoid high surge pressures.

Yes, it is likely the weak zone will fracture. Notice the surge pressure are predicted to be greater than the fracture pressure at the depth of interest.

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Using the

optimized trip time, the pressure no longer exceed the fracture gradient.

Notice the various calculated trip speeds. You would want to use the minimum of these trip speeds to avoid fracturing the weak zone.

WellPlan Exercie Book

WELLPLAN

Exercise Book

2003.5.0.2 (EDM 2003.5.0.2 (03.13.03))

Contents

WELLPLAN Exercise Overview

Exercise 1: Creating the Data Hierarchy

Exercise 2: Specifying Tubular Properties, and

Working With Catalogs

Exercise 3: Using the Case Menu

Exercise 4: Using Torque Drag Analysis

Steps and Questions

Answers

Exercise 5: Using Hydraulics Analysis

Steps and Questions

Answers

Exercise 6: Using Well Control Analysis

Steps and Questions

Answers

Exercise 7: Using Surge Analysis

Note

Steps and Questions

Answers