You will review the analysis options available within the Notebook module.
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.
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.
10. Create a case for design P1. Name the case 14 3/4” Hole Section.
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
• Internal Yield: 9,940 psi
• Collapse Resistance: 6,540 psi
• Body Yield Strength: 2,352,010 lbf
• 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.
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
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:
• 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
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
9-P-100 3.685 150 2790 900
10-P-130 3.984 140 3595 1170
12-P-160 6.433 120 3200 1440
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.
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.
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)
10. Does the Drag Chart analysis predict any problems in this interval?
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.
17. If the buckling near the bit is still a problem, what could you do?
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.
8. Use Case > Torque Drag Setup
9. Use Parameter > Run Parameters
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.
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.
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.
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.
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.
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
• 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 Loss) At 425 gpm, what is the pressure loss gradient (psi/ft)
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.
Record the bit, string, and annular pressure losses.