A selection of quick start guides for Innova Engineering
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A guide to the Apparent WOB Chart within Innova Engineering
Once a T&D calculation has been run, you can check the Apparent WOB Chart:
TAD Results - Drilling Charts - Apparent WOB (for the plot)
TAD Results - Drilling Data - Apparent WOB (for the Data Table)
This plot shows the Apparent WOB (Sliding) you need to see at surface (at each depth) in order to Actually have 15klbs WOB.
For example, in the above chart. @ 600ft MD with CH 0.25 OH 0.30 FF's, you would require 36.5klbs Apparent WOB (as seen on the drillers screen) to Actually have 30klbs WOB.
Once a T&D calculation has been run, you can check the Apparent WOB Snapshot Chart:
TAD Results - Snapshot Charts - Casing Wear (for the plot)
TAD Results - Snapshot Data - Casing Wear (for the Data Table)
This snapshot plot shows the Apparent WOB (Sliding) you will see at surface (for any one specific depth, which is displayed in the chart title) vs the Actual WOB.
For example, in the above chart. @ 11,820ft MD with CH 0.10 OH 0.15 FF's, with 35klbs Apparent WOB (as seen on the drillers screen) you would expect to have an Actual WOB of 30klbs.
A guide to the Casing Wear chart within Innova Engineering.
Once a T&D calculation has been run, you can check the predicted casing wear:
TAD Results - Snapshot Charts - Casing Wear (for the plot)
TAD Results - Snapshot Data - Casing Wear (for the Data Table)
The casing wear is expressed as depth in ether inches or mm depending on what units are selected for Diameter. The depth of wear indicates depth of the groove which will be worn in to the side of the casing over a period of time.
This is calculated based on:
Side force (calculated)
ROP (Engineering Parameters tab - Torque and Drag section)
Length of the open hole section (Drill string, Well Geometry & Fluids tab - Well Geometry Section)
rpm (Engineering Parameters tab - Torque and Drag section)
Casing wear factor (Engineering Parameters tab - Torque and Drag section)
Casing Wear Factor – Casing wear factor, is defined as the ratio of friction factor to specific energy, E-10psi-1. The table below should be used as guide for casing wear factor selection.
This is a snapshot chart, which shows the predicted cumulative wear at each point in the casing when the assembly is at 11,820ft MD.
Casing Wear Rotating: This is the predicted wear on the casing when the string has 0 ROP
Casing Wear SO: This is the predicted casing wear calculated using the reaming slack off
A guide to the drill pipe fatigue plot within Innova Engineering
Drill string fatigue will only occur while rotating and only while rotating over a dogleg. The more tension within the pipe the more likely it is to get fatigued. There is a critical value of dogleg where fatigue failure becomes an issue.
The Drill Pipe Fatigue Chart, is a snapshot chart which displays the actual dogleg and the critical dogleg at every point in the string for a given depth. If the actual dogleg is greater than the critical dogleg then fatigue failure is a potential issue.
The critical dogleg curve is generated based on the free rotating weight of the drilling assembly. One point to note is that back reaming will increase the tension and therefore reduce the critical rotating dogleg; however, this has not been included in the chart because back reaming operations do not generally last too long.
Once a T&D calculation has been run, you can check the Drill Pipe Fatigue Chart:
TAD Results - Snapshot Charts - Drill Pipe Fatigue (for the plot)
TAD Results - Snapshot Data - Drill Pipe Fatigue (for the Data Table)
A guide to the hole cleaning charts within the Innova Engineering hydraulics module.
In the Hydraulics Module of Innova's Engineering software, there are 4 plots dedicated to hole cleaning. This document is a guide to these plots and how to interpret the results.
Once a hydraulics calculation has been run, you can check the hole cleaning charts by going to: Hydraulics Results - Hole Cleaning.
Flow rate is the dominant factor in cuttings removal while drilling directional wells. An increase in flow rate will result in more efficient cuttings removal under all conditions. However, how high a flow rate can be increased may be limited by:
The maximum allowed ECD
The susceptibility of the open hole section to hydraulic erosion
The availability of rig hydraulic power
This is a snapshot chart and shows the Annular Velocity at all different points in the wellbore when the assembly is at a given depth for various different flow rates.
CCI (Cutting Carrying Index) is a measure of how clean a vertical (0-35° inc) well is.
0.5 or less and hole cleaning is poor & problems may be seen
Greater than or equal to 1.0 indicates good hole cleaning
Annular Velocity and Mud weight (along with PV & YP values) are used in this calculation. The higher the annular velocity, the higher the CCI.
For sections of the wellbore where the inclination is greater than 35°, hole cleaning should be evaluated using the Cuttings % Plot.
This is a snapshot chart and shows the CCI at all different points in the wellbore when the assembly is at a given depth for various different flow rates.
The Cuttings % plot represents the percentage of the annulus which is taken up with cuttings. Anything above 5% should be considered a problem.
Unlike the CCI plot, this measure of hole cleaning is not limited by inclination and can be used for any well profile. This calculation is also affected by ROP. Increased ROP, increases the cuttings %.
This is a snapshot chart and shows the Cuttings % at all different points in the wellbore when the assembly is at a given depth for a given ROP at various different flow rates.
The minimum flow rate plot is a snapshot chart which shows the minimum flow required to keep the hole clean at all points in the wellbore for a range of ROPs at a certain depth.
The ROP value selected in the hydraulics setup (in this example 10m/hr) will be used as the lowest ROP and 4 additional ROP values will be displayed which are automatically generated by the program and are pre set percentages of the original (125%, 150%, 200% & 250%). These percentages are built into the program and are not adjustable by the user.
To interpret the plot, you need to find the largest flow rate for any one ROP and that will be the minimum flow that is required at that depth to keep the hole clean. This can be done by using the Screen Reader or the data table.
In the plot above, for an ROP of 12.5m/hr @ 1006m MD, the minimum flow rate required to keep the hole clean would be ~1,512 lpm.
A guide to Innova's QAQC, Short Collar Correction (SCC) and Multi Station Analysis modules within Innova Engineering.
The following document is a guide to Innova's QAQC, Short Collar Correction (SCC) and Multi Station Analysis modules within Innova Engineering.
The purpose of this document is to guide a new user through the layout, setup, calculation and outputs for these modules.
This module takes raw data from the MWD accelerometer (GX, GY & GZ) and magnetometer (HX, HY & HZ) and checks the generated outputs against the local geomagnetic data to ensure that the survey falls within accepted tolerances.
In order to run the QAQC check, the following inputs are required.
RAW Survey Data section of the Surveys tab
Latitude: Required to calculate the SCC Delta Azi in the Magnetic Spacing Calculator
HL Ref – Reference magnetic field
Dip Ref – Reference magnetic dip angle
TAC – Total Applied Correction - Automatically calculated based on North Reference selected
Grid convergence – Angle between True North & Grid North from True North
Declination – Magnetic declination - Angle between True North & Magnetic North from True North
North reference – The north reference the surveys are referenced to. Either True or Grid.
This data is generally obtained from the well planning department who generate the data using programs like IGRF, BGGM & HDGM.
Magnetic Units associated with HX, HY & HZ.
Geolink / Tensor (mv), SSP / SUCOP (uT), nT, nT no XY inversion, EVO / Applied Physics or Vertex
Accelerometer Units: Associated with GX, GY & GZ.
G or mG. The option to Invert Z Axis can be checked or unchecked irrespective of the accelerometer unit choice
Raw data from the MWD tool (GX, GY, GZ, HX, HY & HZ) + Measured Depth
It is important that the correct QC limits are set. These values are the ± limits used to compare the measured values against the calculated values. If these limits are not accurate it is possible that surveys may pass, which should not pass and conversely surveys may fail, when they should pass.
The QC default limits set in Engineer are industry standard. It is however possible to change these if required. You can do this as follows:
In the Surveys tab, select Raw Surveys from the Survey Selection drop down.
Select Options from the top toolbar and then Raw Survey QC Limits.
Note, that you can only access these values when you have Raw Surveys selected.
Individual limits can now be changed as required.
Note, that any changes made to these limits will only be valid for each specific project. When creating a new project, limits will be the default values until changed.
Ensure that the correct units have been selected, fill in the RAW Surveys Tab data (HL, Dip etc) and ensure that you have the correct RAW survey QC limits assigned.
Ensure that you have the correct survey calculation method selected: Options - Survey Calculation Method. The default is Minimum Curvature and is very unlikely to be anything other than this.
Select Raw surveys from the survey selection drop down menu.
You can now enter your raw MWD data on a survey by survey basis, or if you are retrospectively checking an existing survey you can add the whole thing in one go
You can copy and paste the data, or
Go to File - Import Survey - you can then select the file you want to import
Note that in the drop down file type menu, there is an option that says Navigator SCC .txt. This should be used when importing Navigator export files (Navigator export files also contain the Geomag data; therefore, once imported ensure the Geomag data that has been pulled in is correct)
The generated HL, GT and Dip values are compared to the reference data in the RAW surveys Tab and any of the generated values out with the selected QC limits will be highlighted in RED. For a survey station to pass the QAQC procedure, they must fall within the QC limits and therefore not be highlighted.
Any surveys which have been highlighted should be rejected and retaken, unless it is possible to use the Short Collar Correction (SCC) algorithm to correct them to within the accepted limits.
The values in the SCC column's will be generated regardless of whether a survey passes QAQC or not, and should therefore be disregarded, unless of course you are using the correction.
Short Collar Correction (SCC) corrects for magnetic interference in the Z axis. It should be noted that for the short collar correction algorithm to work correctly the Z axis must be aligned with the hole direction i.e. the Z axis points along hole. If this is not the case the short collar correction algorithm will not work. All major MWD companies with the exception of Schlumberger have the Z axis aligned with the along hole direction.
Firstly, you need to ensure that the following data has been added to Engineering.
Proposed BHA with the relevant components marked as non-magnetic
Well Plan, in the Surveys Tab under Well Plan Surveys
Raw Survey Data section and Sensor offset in the Survey Corrections section
You can now calculate the well path magnetics: Calculate - Wellpath Magnetic Interference
A window will now appear with the results and will look like the screen shot below.
Results
Azimuth: The azimuth displayed is referenced to Magnetic North and will therefore look different when compared to the azimuth that was entered in the plan (which could be referenced to Grid or True North). The correction applied to the input azimuth is automatic and is based on the Geomagnetic data that you have entered in the Raw Survey Data Section.
Delta Bz: The expected error between the Theoretical Bz and the Measured Bz (from MWD) for raw, uncorrected surveys.
Delta Azimuth: The expected error in the raw uncorrected azimuth reading, <0.5 degrees is considered acceptable
Delta Dip: The expected error between the calculated dip (from the geo-mag data) and the actual measured value (from MWD). This will be highlighted in red if the value is greater than the tolerance entered in the QC Limits dialog.
Delta HL: The expected error between the calculated magnetic field strength (from the geo-mag data) and the actual measured value (from MWD). This will be highlighted in red if the value is greater than the tolerance entered in the QC Limits dialog.
Theoretical Bz: The theoretical magnetic field strength expected in the Z axis with no interference.
SCC Delta Azi: The expected error in the SCC corrected azimuth, <0.5 degrees is considered acceptable. This is affected by the Latitude entered in the Raw Survey Data section.
The P1 and P2 pole strength values are automatically selected based on the component type and size above and below the non mag components in the string. These can be overridden by the user if necessary, by checking the override pole box at the bottom right of the dialog and alternative values can then be entered by the user. Once entered, the user must select recalculate.
The whole output can be saved to pdf by selecting File – Export to PDF.
The data table can be exported to Excel by selecting File - Export.
These results can be used to make an informed decision as to whether there is a requirement to run the SCC algorithm, add additional non-mag or do nothing. Company policy will dictate what error values are considered acceptable.
When it is deemed necessary to run SCC, careful consideration should be given to the planned well path, as there are defined limitations to the SCC which must be adhered to. Failure to follow these guidelines could result in surveys passing correction which should not. The SCC limits are listed in the table below.
Note 1 – If possible, SCC should NOT be used and the BHA should be correctly spaced with non-magnetic tubulars as required.
Note 2 – SCC must NOT be used if the well path is known to be within these parameters. Again, the BHA should be correctly spaced with non-magnetic tubulars as required.
If the above parameters are encountered, then the SCC algorithm will not function correctly and erratic corrected data will be seen. It is therefore necessary to discuss beforehand with the Directional Driller/Company Representative as to an agreeable plan of action if the above criteria are expected to be encountered during the drilling that particular borehole.
If the planned wellbore falls out with the above limitations, SCC should NOT be used, and you should ensure that the BHA has the correct non-mag spacing.
When running the SCC, raw survey data is added in the same way as you do for the QAQC.
As with the QAQC, any numbers which are out of spec are highlighted red and should not be used. However, there are 3 columns (Azi SCC, HL SCC & Dip SCC) which contain corrected values, and as long as all 3 of these columns are not red, the Azi SCC value can be used instead of the calculated azimuth.
If even one of these 3 cells are red, the corrected azimuth should not be used, and the survey should be retaken.
Multi Station Analysis is a technique which can be used to calculate Magnetometer biases in the X, Y & Z axis. This is achieved by examining the measured and theoretical values at each sensor over multiple stations to find corrections which minimise the errors. These corrections are then applied to all the raw values to produce corrected surveys.
This section will assume that the user has input all data required to run SCC, as these steps must be complete before MSA can be calculated. In the Surveys tab on the main screen, select the MSA radio button located at the bottom right of the screen, this will open the Multi Station Analysis dialog.
All the RAW surveys populated on the main screen can be found here – Note that these inputs are NOT editable on this page.
The HL Ref box located at the top left of the screen will contain the value entered on the main surveys tab. This can however be changed on this screen if a more accurate value is supplied e.g. from an IFR model
MSA Parameters: The user can select the required Bias and SF start, stop and Step values. If the LSQ fit does not show a good curve with a minimum found these values can be adjusted to extend the range of the calculation. Changing the step size can speed up / slow down the calculation but a smaller step size can increase the accuracy.
Values in Use: The user can choose which values to use for the calculation:
Bz: Choose between SCC or raw. This determines which Bz value is used in the MSA calculation. If there is a large amount of interference in the Z axis, select the SCC option as the Z axis interference from the drill string must be removed before the MSA calculation can be run. If, however the BHA is correctly spaced or the assembly is run in the SCC no-go zones, then the raw value should be used.
Azimuth: This selection determines which azimuth is used in the survey calculation and only affects TVD, NS, EW, DLS etc
Inclination: This selection determines which inclination is used in the survey calculation and only affects TVD, NS, EW, DLS etc
Apply Gt Weighting: Surveys at a higher inclination are given more weighting in the calculation than surveys at lower inclinations. This is because they have more of an effect on azimuth. Ticking this box defines if the weighting is applied.
Override Correction: When this box is ticked the user can manually edit the Bias X, Y, Z and Scale X, Y, Z values.
To run the MSA calculation, select the “Calculate MSA” radio button. The MSA columns will populate with the relevant corrected values. As with the SCC results, anything out of spec will be highlighted in red.
At the left-hand side of the screen, if required the user can deselect any survey station which is out of spec. Once the relevant surveys have been deselected it is possible to rerun the calculation. The lines which have been deselected will have blank cells in the MSA columns, and this station will not be included in the calculation.
The MSA report and output charts are separate from the QAQC and SCC reports.
Once a calculation has been run, if required the user can generate a report. This can be done by either selecting the Report icon or by going to File - Print Reports.
Select the Surveys tab and select raw surveys. It is possible to create the report as PDF or Excel. Then select File - Print.
The MSA reports are accessed directly from the MSA window and are NOT available from the Print Reports section. Once MSA has been calculated the user can select File – Print Report.
This generates a PDF report which includes the MSA results, Magnetics, Pseudo Bias & SF values and a listing of the corrected surveys. Note that any stations which were deselected will not appear in this listing.
The user can also export the main MSA data table, as displayed on the main MSA interface. This can be exported as a .txt or Excel file. To export this data, select File – Export.
In addition to the reports, the View menu contains QA/QC and other tools to evaluate the data.
The LSQ Data table shows the data from the least squares fit
The Azimuth Comparison chart, provides the user with a visual representation of the Uncorrected azimuth against the SCC corrected azimuth and the MSA azimuth.
The HL comparison chart gives the user a visual representation of the reference HL against the measured (uncorrected) HL and the SCC & MSA corrected HL values. The chart also includes the tolerance lines which make it very easy to quickly identify any points which are out with the QC parameters
The Dip comparison chart gives the user a visual representation of the reference Dip against the measured (uncorrected) Dip and the SCC & MSA corrected Dip values. The chart also includes the tolerance lines which make it very easy to quickly identify any points which are out with the QC parameters
The BH BV Scatter Plot shows the horizontal and vertical components of the sensor readings plotted against the QC values. Ideally, they should all reside within the limits
The LQS Chart shows the least squares fit. If a V shape curve is seen the minimum has been found and the calculation is a success. If any one of the charts does not show a “minimum found” the calculation must be re-run.
This Chart plots the difference in the RAW and MSA corrected azimuths against the HSTF recorded when the survey was taken. This chart gives a good visual representation of the number of surveys taken in each quadrant. For best results, an even spread is ideal, but it is essential that there are at least some survey points in each quadrant.
The Delta Azi Plot shows the difference in azimuth between the MSA and RAW azimuth and the SCC and RAW azimuth.
The Delta Dip Plot shows the difference in the dip between the MSA and RAW dip and the SCC and RAW dip.
The Delta HL Plot shows the difference in the HL between the MSA and RAW dip and the SCC and RAW dip.
This plot shows the difference between the corrected and uncorrected surveys in the plan view.
This plot shows the difference between the corrected and uncorrected surveys in the section view.
The GT Plot shows the measured GT values against the value entered in the magnetics section.
Selecting this option, displays labels on the BH BV Scatter plot.
Allows the user to select which plots to include in the reports.
A guide to the Hydraulics module within Innova Engineering.
This document will deal with the Hydraulics module within Innova Engineering and will detail the steps required to run these calculations.
Units: It is important to ensure that the correct Units are selected before you do anything else as changing units after the data has been input can lead to mistakes. Note: If air drilling is being modelled, SFCM must be selected as the Flow units to activate air drilling mode.
Note: If the unit for Flow is selected as SFCM in the Units Menu, Engineering will assume that air drilling is being modelled. In this case the calculation will ignore Mud Weight, PV, YP and Mud Rheology, and instead assume the properties of air as the drilling fluid.
Hydraulics Model Options should then be checked from the Options menu. These mostly relate to the surge and swab calculations.
Surge and Swab is calculated by breaking down the measured depth into sections of a given length (Stand Length), where 30m / 100ft is the default. The program then does a lumped surge and swab calculation over this course length, where the pipe accelerates from 0 to the desired trip speed and then decelerating back to zero.
The acceleration and deceleration phases are calculated based on the trip speeds entered in the Engineering Parameters tab; the higher the trip speed the larger the acceleration effect. The generated outputs in the plot and data table, are the maximum surge or minimum swab values calculated over this interval.
Below is a description of each option:
Surge and Swab Parameters:
Mud Compressibility: A compressibility factor for the mud in 1/psi. Default for most oil-based fluids is 3 x 10-6.
10m Gel Strength: 10-minute gel strength, used to calculate the additional surge pressure required to break down the gels. Default is 12.
Stand Length: Length of the stand used in the calculations. Default is 30m / 100ft.
SnS - Include Pipe Acceleration: This option allows the user to include or exclude pipe acceleration. When this is included, the calculation will use an acceleration and deceleration phase for each stand length. When it is not included, the trip speed will be used for the whole stand with no acceleration or deceleration phase. Default is Off.
SnS - Include Gel Strength Pressure Loss: Include the additional pressure required to break down the gels. This is normally a relatively small value. Default is Off.
SnS – Continuous Circulation: Used to model coiled tubing. Assumes circulation while tripping, this means that swab affects will be less and surge effects will be more depending on flow rate. The first flow rate in the flow grid of the Engineering Parameters tab is used to determine the annular velocity generated by the circulating fluid. Default is Off.
SnS – Limit Acceleration Effects: This option limits the additional surge pressures due to acceleration to a maximum of 2 x the current max surge pressure. This stops very large (artificial) equivalent mud weights being generated when very shallow. Default is On
SnS – Continuous Tripping: This option assumes continuous tripping, and as a result will only calculate one acceleration phase (on the first stand length) and one deceleration phase (on the last stand length). This option is best used to model coiled tubing. Default is Off.
SnS – Use Bit TFA for Open Ended Calcs: This option allows the user to use the bit TFA when running open ended surge and swab calculations. This will only work for assemblies which have a bit and a TFA entered. When this selection is off, the program uses the internal diameter of the last component. Default is Off.
Pump Pressure Safety Factor: This option allows the user to increase the SPP by a specified percentage. Pipe Pressure Loss, Annular Pressure Loss and SPP values are all adjusted to reflect the input Safety Factor.
MPD Data: This option allows the user to enter a back pressure for Managed Pressure Drilling.
MPD Setup. The MPD Back Pressure is added as a fixed value to all of the SPP calculation totals and will also be reflected in the ECDs.
EMW Calculator: The user inputs the desired EMW increase at a specific TVD and the required back pressure to be applied is calculated. The user can then enter this value in the MPD setup.
Riser Boost Rate: The boost flow rate across the riser is entered here. This additional flow in the riser annulus affects the annular pressure loss, annular velocity, hole cleaning and ECDs in the riser only. This in change in the riser values affects the SPP, annular pressure loss, hole cleaning and ECDs for the section. This is only applicable in wells where the Well Geometry includes a ‘Riser’. If the well geometry does not include a riser, any value entered here will have no effect on the calculated outputs.
In order to run Hydraulics, the following inputs are required.
Drill String, Well Geometry & Fluids Tab
Drill String: Input the assembly as accurately as possible including the drill pipe to surface (note, for the last component e.g. DP to surface, the user does not have to input the exact length as the program will do this automatically based on the calculation depth. Inputting a value of 10 is fine). Note that once you have selected the component type it is possible to right click on the line and select "select from Library", which will open the components library.
Input the dimensions of the drill sting components into the Drill String grid:
Description: A description of the component entered, this is only used in the generation of reports and plays no part in any of the calculations.
OD: The outer diameter of the component in inches.
ID: The inside diameter of the component in inches.
TJ OD: If the component has a tool joint (such as drill pipe) enter the OD in inches into this column. If the “Include TJ in calculations” menu option is turned off this column will be disabled.
TJ ID: If the component has a tool joint (such as drill pipe) enter the ID in inches into this column. If the “Include TJ in calculations” menu option is turned off this column will be disabled.
Length: The length of the component in the system units.
Component: Select the component type from the drop-down list. The type of component that is selected will determine the properties displayed in the lower components grid.
Bit TFA: This is selected in the component details section when the bit is selected. The user can select a fixed TFA or can input multiple nozzles and sizes and a TFA will be generated based on this selection.
Motor Pressure Drop: This is selected in the component details section when the motor is selected.
MWD Pressure Drop: This is selected in the component details section when the MWD is selected.
Well Geometry: Input casing, liner and open hole details including depths and ID's. For Open hole, the ID is the OD of the bit.
Mud weight: Mud density used in all hydraulics calculations
PV: Mud plastic viscosity only used if Bingham Plastic hydraulics model is selected
YP: Mud yield point only used if Bingham Plastic hydraulics model is selected
Mud Rheology: The Fann dial readings of the drilling fluid, required for all hydraulics models except Bingham plastic.
Surveys Tab
Survey Selection: Hydraulics calculations can be run against surveys and well plans. Data can be input as measured depth, inclination and azimuth in both Actual Surveys or Well Plan Surveys and the program will generate the rest of the numbers using whichever survey calculation method you have selected (Minimum Curvature Default). Hydraulics cannot be run against surveys input the RAW surveys section. Either enter the plan or surveys manually, import them or copy and paste the data directly into the cells.
Engineering Parameters Tab
This is where the user can select the parameters they want, to run the Hydraulics calculation.
Hydraulics Model –four models are included as standard
Bingham Plastic
Power Law
Herschel Bulkley
Robertson Stiff
Bingham plastic uses PV and YP and mud weight, all other models use the fann readings and mud weight.
Surge / Swab – Specifies if the surge and swab calculation to be carried out is open or close ended. If modelling for a casing or liner assembly and close ended is used, the pressure loss through the float / shoe is taken into account.
Surge / Swab Reference – This is the reference point for the surge / swab calculation, select some common references from the combo box such as bit, shoe and bottom hole or click on the check box to enable a user defined depth.
User defined depth – Only active if the enable check box has been ticked, this will disable the surge / swab reference combo above and the surge and swab reference depth can be entered in the edit box.
ROP – Rate of penetration, this is used to calculate the cuttings loaded ECD’s and other hole cleaning parameters.
RPM – The rotational speed of the drill string. Additional pressure will be added based on the RPM.
ECD Adj – ECD adjustment is manual adjustment to all the ECD curves in order to better match the model with MWD PWD data.
SW Den – Sea water density, which is used for riserless drilling calculations
Surface Pressure Losses – The pressure loss through the surface equipment. This value is added to the total standpipe pressure calculated by the model.
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Flow rate: This grid allows the flow rates for the hydraulics model to be entered. By default, the manual flow increment box is unchecked, and the user enters a flow rate in the middle cell of the grid. The software then automatically calculates flow rates above and below this base rate (±25% & 50%) with which to perform a sensitivity analysis. If you wish to override the automatic values generated, click the enable manual flow increment check box. This will leave the user with a single line and once filled a new line will be added. An unlimited number of flowrates can be entered.
Survey Selection: The user can select either Well Plan Surveys or Actual Surveys. There is also an option to select Composite Listing, which splices the actual surveys into the well plan surveys to create a composite listing.
Tripping Speed: This grid allows the tripping speeds for the hydraulics model to be entered. By default, the manual tripping increment box is unchecked, and the user enters a tripping speed in the middle cell of the grid. The software then automatically calculates tripping speeds above and below this base rate (±25% & 50%) with which to perform a sensitivity analysis. If you wish to override the automatic values generated, click the enable manual trip increment check box. This will leave the user with a single line and once filled a new line will be added. An unlimited number of trip speeds can be entered but the first trip speed entered will be used for the reports. The tripping speed is used in Surge Swab calculations.
Once the user has completed all the required inputs the calculation can be run. To do this, select either the icon displayed below, or select Calculate - Hydraulics
Once a calculation has been run, the hydraulics results section of the Engineering Parameters tab will be populated with the results. The results displayed are for the flow selected at the top right of this section. This flow is a drop-down menu which will contain the same flows input during the setup, so if only one flow was used, there will be only one available here. The depth can also be adjusted by clicking on the arrows to the right of the depth and it will scroll in 30m / 100ft intervals and display the results based on the depth and flow selected.
Note that whatever results are displayed in this section (based on the flow and depth selected), will be output in the summary report.
Once the calculation has been run, the Hydraulics Summary Report can be viewed by selecting the icon from the toolbar at the top of the screen. This contains an overview of the main values associated with the calculation and can be saved as a pdf.
If required, a more detailed report can be generated by selecting "File" - "Print Reports” or selecting the icon on the toolbar (highlighted above). The required data can be selected, and a report can be generated either as excel of pdf. Note that when excel is selected the chart selection will be greyed out as these can only be output as pdf.
Some of the Hydraulics results are available to view by selecting the toolbars along the top. This is a quick way to access some of the more commonly used plots.
All the Hydraulics plots and data are available to view by selecting the Hydraulics results at the top of the screen. The Data options display the numerical data used to generate the charts. Note that there is no option to view the data for the Annular Velocity Profile, CCI and Cuttings % Charts.
The hydraulics charts give a graphical representation of the theoretical values you would expect to see as the well is being drilled. Therefore, at each depth, the numbers displayed on the charts and the data tables can be directly compared with values recorded from the SPP gauge and down hole tools, as the well is being drilled.
This chart displays the standpipe pressure (SPP) expected at surface when the assembly is at any given depth. There will be a line displayed for each of the flowrates entered in the hydraulics section of the Engineering Tab. If pump liner data has been added to the pump data dialog in the tools menu, then this can also be represented on the chart via the add series dialog.
This chart displays the following lines for each of the flowrates entered in the hydraulics section of the Engineering Tab:
Clean ECD: The ECD at the end of the string, for any given depth, based on a cutting’s free annulus.
Dirty ECD: The ECD at the end of the string, for any given depth, based on a cutting’s loaded annulus. The volume of cuttings in the annulus is calculated based on the ROP entered in the hydraulics section of the Engineering Tab. If the ROP is entered as zero then the clean and dirty ECD lines will lie on top of each other.
ECD Snapshot: The ECD snapshot line shows the expected ECD at each point in the annulus when the string is at a given depth. This depth relates to the deepest depth represented on the chart. This line is generated based on a cuttings free annulus, which means that the last point for both the Clean ECD line and the ECD Snapshot line will be the same.
A line representing the Mud Weight is also displayed on the chart.
This chart displays the surge and swab lines for each of the tripping speeds entered in the hydraulics section of the Engineering Tab.
The Y axis corresponds to the bit depth (bottom of the assembly being run) regardless of what has been selected as the reference point. The results, however, display the calculated values at the reference point based on the bit position. So if for example you have the reference point selected as the bottom of the hole, when you look at the chart, it will be displaying the surge and swab pressures at the bottom of the hole, when the bit is at any given depth.
The reference point is selected in the hydraulics section of the Engineering Tab and is displayed at the top of the chart.
Innova Engineering Hydraulics Module contains 4 (snapshot) hole cleaning charts. A basic explanation is given below. For a more detailed explanation of these, see Innova's "Hole Cleaning Guide".
Flow rate is the dominant factor in cuttings removal while drilling directional wells. An increase in flow rate will result in more efficient cuttings removal under all conditions. However, how high a flow rate can be increased may be limited by:
• The maximum allowed ECD
• The susceptibility of the open hole section to hydraulic erosion
• The availability of rig hydraulic power
This is a snapshot chart and shows the Annular Velocity at all different points in the wellbore when the assembly is at a given depth for the various flow rates.
CCI (Cutting Carrying Index) is a measure of how clean a vertical (0-35° inc) well is.
• 0.5 or less and hole cleaning is poor & problems may be seen
• Greater than or equal to 1.0 indicates good hole cleaning
Annular Velocity and Mud weight (along with PV & YP values) are used in this calculation. The higher the annular velocity, the higher the CCI.
For sections of the wellbore where the inclination is greater than 35°, hole cleaning should be evaluated using the Cuttings % Chart.
This is a snapshot chart and shows the CCI at all different points in the wellbore when the assembly is at a given depth for the various flow rates.
The Cuttings % plot represents the percentage of the annulus which is taken up with cuttings. Anything above 5% should be considered a problem.
Unlike the CCI plot, this measure of hole cleaning is not limited by inclination and can be used for any well profile. This calculation is also affected by ROP and RPM. Increased ROP, increases the cuttings %.
This is a snapshot chart and shows the Cuttings % at all different points in the wellbore when the assembly is at a given depth for a given ROP at various different flow rates.
The minimum flow rate plot is a snapshot chart which shows the minimum flow required to keep the hole clean at all points in the wellbore for a range of ROPs at a certain depth.
The ROP value selected in the hydraulics setup (e.g. 10m/hr) will be used as the lowest ROP and 4 additional ROP values will be displayed which are automatically generated by the program and are pre-set percentages of the original (125%, 150%, 200% & 250%). These percentages are built into the program and are not adjustable by the user.
To interpret the plot, the user needs to find the largest flow rate for any one ROP and that will be the minimum flow that is required at that depth to keep the hole clean. This can be done by using the Screen Reader or the data table.
A step by step guide to installing Innova Engineering.
Innova engineering can be supplied as a zipped installation file which must be unzipped before use. Right click on the file and select “Extract All….” From the context menu.
Select a location which you wish to extract the files to and click “Extract”. The installation files will be extracted to the selected location in a folder called “Innova Engineering”
Once the files have been extracted, open the Innova Engineering folder and double click on the “Innova Engineering vx.x.x.exe” file to begin the installation process.
Select the location which you wish to install Innova Engineering. The default location is “C:\Program Files (x86)\Innova Drilling and Intervention\Innova Engineering”. If you wish to change the location the program is installed to click on the “…” button.
Click on “License terms and conditions”. This will display the below screen.
Read the terms and conditions. This information can also be printed for future reference by selecting the printer icon. Once read, select the “Accept and Install” button to begin installation.
If the copy of Innova Engineering is genuine the user will be presented with a dialog showing the verified publisher as “Innova Drilling & Intervention”. If not the software is not genuine and should not be used. Click “Yes” to continue the installation.
Once the installation is complete the final dialog will display “Innova Engineering has been successfully installed”. Select “Finish” to close the dialog. An icon will have been added to the desktop and an entry for “Innova Engineering” will be in the start menu.
A guide to the Torque & Drag module within Innova Engineering.
This document will deal with the Torque & Drag module within Innova Engineering and will detail the steps required to run these calculations.
In the options menu, there are selections that affect the way the torque and drag calculation is run and these should be double checked.
Units: Ensure that all units are correctly selected, based on requirements. Note: If air drilling is being modelled, SFCM must be selected as the Flow units to activate air drilling mode.
Include Tool Joints: Select whether the OD and ID of the tool joint is included in the calculations. Default is Yes.
Include Stabilizers / Centralizers: Enables or disables drill string stabilisers or casing centralisers. Default is Yes.
Include Drilling Data in Calculation: Determines if data entered in the Drilling Data tab is used in the hydraulics and torque and drag calculations. If yes is selected the mud weight, mud rheology, ROP and RPM are used at the depths specified in the calculations. This option is useful for comparing field data to modelled data. By default, this option is set to Yes.
Torque & Drag Model: Select the T&D setup you would like to run.
o Viscous Drag: Refers to the drag caused by pulling the string through the mud. This only affects pick-up weights. Default is No.
o Buckling Friction: The additional friction added if the pipe is helically buckled and being pushed through the well. Only applies to slack-off weights. Default is No.
o Contact Surface Correction: Additional friction applied based on the surface area of the tubular touching the well bore i.e. casing has more friction because more surface area. Default is No.
o Calculate Casing Wear: If No is selected, there will be no output in the Casing Wear Plot. Default is Yes.
o Buckling Lines: User can select between Sliding & Rotary. This selection determines which buckling lines are displayed on the Tension On & Off Bottom Snapshot Charts. Default is Sliding.
o Buckling Model: Determines the way the Helical Buckling limit is calculated.
Conservative (Unloading Model): Sinusoidal limit x 1.4. This is the default.
Standard (Loading Model): Sinusoidal limit x 2.1
o Include Friction Reduction Subs: Friction reduction inputs are available in the DP & HWDP component details. This option determines whether these inputs are used in the calculation. Default is Yes.
o Include Overpull In Stretch Calcs: Stretch calculations will take into consideration the overpull entered in the Engineering Parameters tab. Default is No.
o Outer String Properties: Required input for Liner Expansion calculations.
o Step Interval: Determines the interval between calculated points. Default is 10 i.e. outputs are generated every 10 meters or feet. This will be apparent when viewing the data tables.
o Air Drilling Options: To be used when the section is air drilled. User enters the expected standpipe pressure here for the given flow rate. This will calculate the additional string weight caused by drilling on air. Note: If air drilling is being modelled this must be selected.
o Fluid Level: This option allows the user to select the fluid level in the wellbore. The depth entered is Measured Depth, and the program will assume no fluid from surface to this depth. Over this range, there will be no buoyancy factor considered, therefore the hookload will increase as a result.
Pipe Tensile Yield Limits: Allows the user to enter a pipe size and yield limit into the grid. This can then be displayed on any of the charts via the add additional series button. This input does not affect any calculation. It is instead a reference which can be added to the required charts.
To run Torque & Drag, the following inputs are required.
Drill string, Well Geometry & Fluids Tab
Drill String: Input the assembly as accurately as possible including the drill pipe to surface (note, for the last component e.g. DP to surface, the user does not have to input the exact length as the program will do this automatically based on the calculation depth. Inputting a value of 10 is fine). Note that once you have selected the component type it is possible to right click on the line and select "select from Library", which will open the components library.
Input the dimensions of the drill sting components into the Drill String grid:
Description: A description of the component entered, this is only used in the generation of reports and plays no part in any of the calculations.
OD: The outer diameter of the component in inches.
ID: The inside diameter of the component in inches.
TJ OD: If the component has a tool joint (such as drill pipe) enter the OD in inches into this column. If the “Include TJ in calculations” menu option is turned off this column will be disabled.
TJ ID: If the component has a tool joint (such as drill pipe) enter the ID in inches into this column. If the “Include TJ in calculations” menu option is turned off this column will be disabled.
Weight: This is the weight per unit length of the component, this is either calculated automatically based on the OD / ID of the component or can be entered manually by the user if the “Auto Calculate Weight” option is turned off. This is used for torque and drag calculations as well as SAG calculations.
Length: The length of the component in the system units.
Component: Select the component type from the drop-down list. The type of component that is selected will determine the properties displayed in the lower components grid.
Bit TFA: The bit TFA is required to calculate the pressure drop below the bit, which is used in the buoyancy calculations and in the buckling calculations. This is selected in the component grid section when the bit is selected.
Well Geometry: Input casing, liner and open hole details including depths and ID's. For Open hole, the ID is the OD of the bit.
Mud Weight: This is required for buoyancy and viscous drag calculations
Surveys Tab
Survey Selection: T&D calculations can be run against surveys and well plans. Data can be input as measured depth, inclination and azimuth in both Actual Surveys or Well Plan Surveys and the program will generate the rest of the numbers using whichever survey calculation method you have selected (Minimum Curvature Default). T&D cannot be run against surveys input the RAW surveys section. Either enter the plan or surveys manually, import them or copy and paste the data directly into the cells.
Tortuosity: For portions of a plan which are vertical, it is possible to add tortuosity, to better simulate down hole conditions as a drilled well will never be exactly vertical.
The Engineering Parameters Tab is where the user can select the parameters they want to run the Torque & Drag calculation.
Survey Selection: The user can select either Well Plan Surveys or Actual Surveys. There is also an option to select Composite Listing, which splices the actual surveys into the well plan surveys to create a composite listing.
Flow rate: If manual flow increment is selected, the first flow rate entered will be used in the T&D calculation. If the manual flow increment is not selected, the flow rate entered in line 3 will be used.
Calc Depth – This is the depth the calculation will stop at and the depth the snapshot graphs and tables will display.
RPM – Rotational speed of the drill string, used to calculate reaming torques and hook loads.
Pipe speed – The speed the pipe is moving up and down in depth units / min. Used to calculate reaming hook loads and torques. It is also used to calculate the viscous drag if selected.
WOB Rotate – The weight on bit while on bottom rotary drilling. Used for creating the Apparent WOB & Apparent WOB Snapshot Charts.
WOB Slide – The weight on bit while on bottom slide drilling. If the check box is not selected, this will auto populate with the value in the WOB cell.
Overpull: The overpull applied to the assembly when pulling out of hole. Used for creating the Apparent Overpull & Apparent Overpull Snapshot Charts.
Block weight – The weight of the travelling block.
Block PU – if the weight of the travelling block is different to the block weight while picking up enter it here, click the check box to enable.
Block SO - if the weight of the travelling block is different to the block weight while slacking off enter it here, click the check box to enable.
Optimise Standoff: Used in the casing standoff calculation. This will override the centralizer spacing selected in casing component details and output the spacing required to achieve the desired standoff.
Est Bit Torque – The estimated torque generated by the bit, this is calculated from the WOB and the bit OD (taken from the drill string), however it can be over-ridden with a user defined value by clicking the check box.
Side force units – Specifies the unit length of the calculated side force. It should be noted that if you are using side force to predict casing wear, the default units should be over ridden to side force / per tool joint (e.g. 30ft or 10m).
Casing Wear Factor – Casing wear factor, defined as the ratio of friction factor to specific energy, E-10psi-1. The table below should be used as guide for casing wear factor selection. Default is set to 1.
ROP – The rate of penetration in feet or meters / hour. The ROP is used to calculate the casing wear. This is done by taking the depth of the last casing or liner and subtracting it from the calculation depth. This value is then divided by the ROP to give the time period over which casing wear is calculated.
Friction factor grid – The friction factors for cased hole and open hole. By default, the enable manual increment box is disabled. Enter a friction factor for the cased hole and open hole in the middle cells of each column and values above and below will automatically be calculated (±25% &±50%) in order to perform a sensitivity analysis. If you wish to override this feature, click the check box and enter as many friction factors as required. This can also be used to perform a single friction factor calculation.
Once the user has completed all the required inputs the calculation can be run. To do this, select either the icon displayed below, or select Calculate - Torque and Drag. This will calculate all the torque and drag and the torque and drag snapshot data.
Additionally, the option is available to only calculate the torque and drag snapshot data. To do this, select either the icon displayed below, or select Calculate – Torque and Drag Snapshot. This option reduces the calculation time; however, will not calculate the full standard torque and drag data.
Once the calculation has been run, the Torque and Drag summary report can be viewed by selecting the icon from the toolbar at the top of the screen. This contains an overview of the main values associated with the calculation and can be saved as a pdf.
If required, a more detailed report can be generated by selecting "File" - "Print Reports” or selecting the icon on the toolbar (highlighted below). The required data can be selected, and a report can be generated either as excel of pdf. Note that when excel is selected the chart selection will be greyed out as these can only be output as pdf.
Some of the torque and drag results are available to view by selecting the toolbars along the top. This is a quick way to access some of the more commonly used plots.
All the torque and Drag plots and data are available to view by selecting the TAD results at the top of the screen. The Data options mirror the charts and display the numerical data used to generate the charts.
Survey Data: Only available to select when on the survey tab. This gives a breakdown of the survey data every 10 meters or feet and includes any tortuosity which has been applied.
Stress Data: Gives the user access to the stress data associated with different operations i.e. Rotating off bottom, Sliding etc. Charts for this data can be generated directly from here.
TAD Summary: This option prints a report that includes a Torque & Drag Summary Report, Drillers Hookload Chart and Drillers Torque Chart.
Standoff Summary: This option prints a report that includes a Centralizer spacing summary, Drill String summary, Centralizer Stand-off results, Standoff chart, Side Forces / Centralizer Forces chart and Hookload chart.
The drilling charts represent the calculated (theoretical) values that the driller would expect to see on his gauges as the well is being drilled. Therefore, at each depth, the numbers displayed on the charts and the drilling data tables can be directly compared with values recorded from the drillers gauges as the well is being drilled.
This chart displays the calculated hookload values for tripping in, Rotating Off Bottom and tripping out. It also includes the Reaming In and Out hookloads.
For each operation, there will be a line represented for each set of friction factors entered in the Engineering Parameters tab, apart from the Rotating off Bottom line, of which there will only ever be one.
The minimum weight to helically buckle (Trip In) will also be displayed on this chart. Any tripping in line which crosses this limit will start to experience buckling in the string. At this point it may be difficult to effectively transfer weight down hole and the string may need to be rotated in order to get to bottom. From the chart, you can tell the string depth and hookload when the buckling will occur, but you will not be able to determine where in the string the buckling is occurring.
This chart displays the On and Off Bottom torques. For each operation, there will be a line represented for each set of friction factors entered in the Engineering Parameters tab.
The Reaming Hookload Chart displays the PU & SO weights seen at surface for any given depth in the section, based on a specific string RPM and pipe speed. If either rpm or pipe speed is modelled as zero, the reaming Hookloads will match the drillers Hookloads. A Reaming PU and SO line will be displayed for each set of friction factors which have been modelled.
The Reaming Torque Chart displays the PU & SO torques seen at surface for any given depth in the section, based on a specific string RPM and pipe speed. With a pipe speed of zero, both of these lines will mirror the off bottom torque line in the Drillers Torque Chart. PU & SO Torque lines will be displayed for each set of friction factors which have been modelled.
The Pipe Stretch Chart displays the calculated amount of pipe stretch expected while picking up for any given depth in the section. There will be a line displayed for each friction factor which has been modelled.
This chart displays the number of completed revolutions that the rotary table must be turned in order to turn the bit. A line will be represented for each of the friction factors entered in the Engineering Parameters tab.
This chart displays the apparent weight on bit (WOB) required at any given depth to achieve a user defined Actual WOB. The actual WOB value used is the WOB value entered in the torque and drag section of the Engineering Parameters tab.
To read the chart the user should select the measured depth of interest and note the apparent WOB for each of the friction factors at that depth. These are the WOB values the user will need to register at surface in order to achieve the desired actual WOB down hole at the bit. Note that if no WOB value is entered in the torque and drag section of the Engineering Parameters tab, then this will model as a vertical line.
This chart displays the apparent Overpull (OP) required at any given depth to achieve a user defined Actual OP. The actual OP value used is the OP value entered in the torque and drag section of the Engineering Parameters tab.
To read the chart the user should select the measured depth of interest and note the apparent OP for each of the friction factors at that depth. These are the OP values the user will need to register at surface in order to achieve the desired actual OP down hole at the bit. Note that if no overpull value is entered in the torque and drag section of the Engineering Parameters tab, then this will model as a vertical line.
The snapshot charts represent the theoretically calculated values that you would expect at each point in an assembly when the assembly is at a given depth. For example, when looking at the torque snapshot chart, it will display the torque at each point in the string (for a given depth) from the bit all the way to surface. The surface values will match those of the drilling charts at the depth in question.
This chart displays the effective tension at all points in the string when the string is at a specific depth. This depth is displayed at the top of the chart and is the calc depth entered in the torque and drag section of the Engineering Parameters tab.
The chart displays the following lines:
Rotating off Bottom
Sinusoidal Buckling – Any load line which crosses this buckling line will be representative of Sinusoidal buckling. The depth at which the line crosses will also represent the component in the string which is experiencing the buckling.
Helical Buckling – Any load line which crosses this buckling line will be representative of Helical buckling. The depth at which the line crosses will also represent the component in the string which is experiencing the buckling.
PU – A Pickup line will be represented for each of the entered friction factors.
SO – A Slack Off line will be represented for each of the entered friction factors.
Tensile Limit – The tensile limit will be displayed based on the tensile limits entered in the component details section for each individual component.
String Tension with Overpull – This line is generated based on the overpull entered in the torque and drag section of the Engineering Parameters tab.
This chart displays the effective tension at all points in the string when the string is at a specific depth with a specific WOB. The depth and WOB are displayed at the top of the chart with these values having been entered in the torque and drag section of the Engineering Parameters tab.
The chart displays the following lines:
Rotating off Bottom
Sinusoidal Buckling – Any load line which crosses this buckling line will be representative of Sinusoidal buckling. The depth at which the line crosses will also represent the component in the string which is experiencing the buckling.
Helical Buckling – Any load line which crosses this buckling line will be representative of Helical buckling. The depth at which the line crosses will also represent the component in the string which is experiencing the buckling.
PU – A Pickup line will be represented for each of the entered friction factors.
Sliding – A Sliding line will be represented for each of the entered friction factors.
Tensile Limit – The tensile limit will be displayed based on the tensile limits entered in the component details section for each individual component.
This chart displays the torque at all points in the string when the string is at a specific depth. This depth is displayed at the top of the chart and is the calc depth entered in the torque and drag section of the Engineering Parameters tab. For each operation, there will be a line represented for each set of friction factors entered.
This chart displays the side force at all points in the string when the string is at a specific depth. This depth is displayed at the top of the chart and is the calc depth entered in the torque and drag section of the Engineering Parameters tab.
The chart displays the rotating side force along with the pickup and slack off side forces for each set of friction factors entered.
This chart plots the actual WOB against the apparent WOB when the string is at a specific depth. This depth is displayed at the top of the chart and is the calc depth entered in the torque and drag section of the Engineering Parameters tab.
To use this chart, the user should select the actual WOB they require downhole, and the corresponding apparent WOB is the weight that will be required at surface to achieve this.
This chart plots the actual overpull against the apparent overpull when the string is at a specific depth. This depth is displayed at the top of the chart and is the calc depth entered in the torque and drag section of the Engineering Parameters tab.
To use this chart, the user should select the actual overpull they require downhole, and the corresponding apparent overpull is the overpull that will be required at surface to achieve this.
This chart shows the predicted cumulative wear at each point in the casing when the assembly is at a specific depth. This depth is displayed at the top of the chart and is the calc depth entered in the torque and drag section of the Engineering Parameters tab.
The casing wear is expressed as depth in ether inches or mm depending on what units are selected for Diameter. The depth of wear indicates depth of the groove which will be worn into the side of the casing over a period of time.
Casing Wear Rotating: This is the predicted wear on the casing when the string has 0 ROP. This calculation uses the rotating side force.
Casing Wear SO: This is the predicted casing wear calculated using the reaming slack off. This calculation uses the slack off side force.
Drill string fatigue will only occur while rotating and only while rotating over a dogleg. The more tension within the pipe the more likely it is to get fatigued. There is a critical value of dogleg where fatigue failure becomes an issue.
The Drill Pipe Fatigue Chart is a snapshot chart which displays the actual dogleg and the critical dogleg at every point in the string for a given depth. If the actual dogleg is greater than the critical dogleg, then fatigue failure is a potential issue.
The critical dogleg curve is generated based on the free rotating weight of the drilling assembly. One point to note is that back reaming will increase the tension and therefore reduce the critical rotating dogleg; however, this has not been included in the chart because back reaming operations do not generally last too long.
This chart shows the Internal and External pressure at each point in the string for a given flowrate, when the assembly is at a specific depth. This depth is displayed at the top of the chart and is the calc depth entered in the torque and drag section of the Engineering Parameters tab.
In the flow rate section, if manual flow increment is selected, the first flow rate entered will be used for generating the outputs for this chart. If the automatic range is selected, the flow rate entered in line 3 will be used.
A guide to the jar placement module within Innova Engineering.
This document describes the jar placement module within Innova Engineering and details the steps required to correctly utilise its functionality.
This document describes the jar placement module within Innova Engineering and details the steps required to correctly utilise its functionality.
Units: Ensure that all of the units are correctly selected, based on requirements.
It is suggested that data is input in the following order to increase input efficiency. This is however, just a guide and the user can deviate from this sequence should they wish.
Input data in the Drill String table.
Input data in the Components Details table for each component.
Input the Well Geometry
Input the Mud Weight
Input the survey data into the Well Plan or Actual Surveys table.
Input the Flow Rate
Input the Calc Depth in the Torque and Drag section
Input WOB Rotate
Input Block Weight
Input Overpull if applicable
Select Tools > Jar Placement
To utilise the jar placement functionality, the following inputs are required.
Drill string, Well Geometry & Fluids Tab
Drill String: Input the assembly as accurately as possible including the drill pipe to surface (note, for the last component e.g. DP to surface, the user does not have to input the exact length as the program will do this automatically based on the calculation depth. Inputting a nominal value of 10 is fine). Note that once a component type has been selected, it is possible to right click on the line and choose "select from Library", which will open the components library. The user can then select the appropriate component and insert it directly into the drill string grid.
Bit TFA: The bit TFA is required to calculate the pressure drop at the bit, which is used in the pump open force calculation. This is entered in the bit component details section.
Mandrel Area: The mandrel area of the jar. Sometimes referred to as the pump open area. Used when calculating the pump open force. This needs to be input in the jar component details section.
Stroke Length: The Free Stroke length of the jar. The stroke length of the jar controls the amount of time it takes for the hammer to hit the anvil, the longer the stroke the more time the hammer has to accelerate. Typical stroke lengths vary between 7 – 12”. It should be noted that the stroke length reported by the manufacturers is usually the total stroke length and should be halved for the purposes of this calculation. This needs to be input in the jar (and accelerator if included) component details section.
Well Geometry: Input casing, liner, riser and open hole details including depths and ID's. For open hole, the ID is the OD of the bit. Note that the user should only enter the well geometry which is relevant for the section in question and should not enter the entire casing string here. The open hole MD value entered here, is the value used for Hole Depth in the jar placement dialog, which dictates the deepest bit measured depth used in the neutral point results.
Mud Weight: This is required for calculating the buoyancy factor.
Surveys Tab
Survey Selection: Jar placement calculations will be run using plan or survey data entered in the Well Plan table. In the absence of data in the Well Plan table, data from the Actual Surveys table will be used. Data can be input as measured depth, inclination and azimuth in both the Actual Surveys and Well Plan sections, and the program will generate the rest of the numbers using whichever survey calculation method has been selected (Minimum Curvature Default). Jar placement cannot be run against surveys input in the RAW surveys table. Either enter the plan or surveys manually, import them or copy and paste the data directly into the cells.
Engineering Parameters Tab
Flow rate: If manual flow increment is selected, the first flow rate entered will be used in the calculation. If the automatic range is selected, the flow rate entered in line 3 will be used. The flow rate is used in the Pump Open Force calculation.
Torque and Drag Calc Depth: The value input here will dictate the bit measured depth used in the Jarring Results table.
WOB Rotate: The value input here will display in the WOB cell in the Jar Placement dialogs Drilling Data section. This is used in the neutral point calculation.
Block Weight: Block weight entered here will be added to the values in the HKLD Fire column in the Jarring Results section.
Overpull: If no overpull is specified the jarring results will be calculated for an overpull up to 500 klbs (250 Tons). If an overpull is specified the jarring results will be calculated up to the overpull value x 2
Once the user has entered all the required inputs, the jar placement calculations are carried out automatically when the user opens the Jar Placement dialog via Tools > Jar Placement or selecting the icon from the toolbar.
The Jar Placement dialog displays all the information and results relevant to the jar placement module.
Non-editable display of the drill string entered in the Drill String section of the main UI. Jars are highlighted in green and accelerators in orange.
Non-editable display of the jar and accelerator component details entered in the Drill String section of the main UI. Only Stroke and Mandrel Area affect the jar placement results. All other cells are for reference only.
Stroke: This is the free stroke length and is used in the impact and impulse calculations.
Mandrel Area: Is used in the pump open force calculation.
Non-editable display of drilling data used in the jar placement calculations.
Hole Depth: Value taken from the deepest MD entered in the Well Geometry section of the main UI. Dictates the deepest depth that the neutral point calculation is run.
Mud Weight: Value from the Fluid Properties, Mud Weight cell. Used in the buoyancy factor calculation.
Buoyancy Factor: Calculated using the below formula.
BF = 1 – (MW/k)
Where BF is buoyancy factor, MW is mud weight and k is a (mud weight unit dependant) constant. Buoyancy factor is used in the neutral point and jarring results calculations.
Flow Rate: Value from the Engineering Parameters tab. If manual flow increment is selected, the first flow rate entered will be used in the calculation. If the automatic range is selected, the flow rate entered in line 3 will be used. Used in the pump open force calculation.
WOB: Value from Torque and Drag sections WOB Rotate cell. Used in the neutral point calculation.
Hole Size: Value from Well Geometry, Open Hole, ID cell. Used in the Jar Size Check and Jarring Results calculations.
Inclination at Bit: Interpolated inclination from the survey listing at the Hole Depth. Used in the Weight Below Jar BHL (Air)/(Mud) calculation.
Non-editable display of calculated data.
Jar Size Check: A pass or fail check based upon the jar size and the hole size. This is to confirm that the correct OD jar has been chosen for the given hole size. Note that a Fail in this cell has NO effect on the jarring calculations, which will be run regardless. All this cell does is highlights to the user if the size of the jar selected is suitable for the hole size based on a checklist which can be fully edited by the user. This is a warning and no more.
Jar is in: TENSION or COMPRESSION. Based upon the input data, this cell shows whether the jar is currently in tension or compression.
Weight Below Jar Vertical (Air): The weight below the jar in a vertical well in the absence of a drilling fluid. Calculated by the sum of the component weights (input in the Drill String section of the main UI) beneath the jar.
Weight Below Jar Vertical (Mud): The weight below the jar in a vertical well, taking in to account the buoyancy effect of the drilling fluid. Calculated by multiplying the Weight Below Jar Vertical (Air) by the buoyancy factor.
Weight Below Jar BHL (Air): The weight below the jar at the bottom hole location (the bit depth) in the absence of a drilling fluid. Calculated by multiplying the Weight Below Jar Vertical (Air) by the cosine of the Inclination at Bit.
Weight Below Jar BHL (Mud): The weight below the jar at the bottom hole location (the bit depth), taking in to account the buoyancy effect of the drilling fluid. Calculated by multiplying the Weight Below Jar Vertical (Mud) by the cosine of the Inclination at Bit.
Pump Open Force: The force generated by the flow of drilling fluid through the BHA that acts to open the jar. Calculated by the bit pressure loss multiplied by the Mandrel Area.
Neutral Point: The MD of the point in the drill string that transitions from compression to tension based upon the input data. This is directly affected by the WOB.
Jar to Bit: The distance from the top of the jar to the face of the bit.
Accelerator to Bit: The distance from the top of the accelerator to the face of the bit.
The pump open force chart displays the pump open force versus the flow rate. The green vertical line depicts the currently selected flow rate.
For details on adjusting the chart settings see Appendix A – Context Menu.
The neutral point chart is a neutral point road map, which shows the WOB to avoid at every depth along the well path. The centre of the red area represents the neutral point. The red section represents a ±5% safety margin, and the orange area represents a ±10% safety margin. This gives the personnel on the job a WOB range to avoid for any given MD along the entire well path. Note that the 5% and 10% margins are the default values, but these can be changed based on user requirements via the settings menu.
For details on adjusting the chart settings see Appendix A – Context Menu.
The jarring up chart displays the calculated jarring up impulse and impact at the jar, versus hook load.
For details on adjusting the chart settings see Appendix A – Context Menu.
The jarring down chart displays the calculated jarring down impulse and impact at the jar, versus hook load. The area shaded in red indicates the hook load range in which the string is modelled as being helically buckled. The buckling will occur at some point in the drill string above the jar and simply indicates that it may not be possible to transmit the required weight to cock / fire the jar. This range is indicated in the jarring results table by lines highlighted in Orange.
For details on adjusting the chart settings see Appendix A – Context Menu.
The jarring results table showing the results of the jarring calculations. These results are the source of the data that is plotted in the Jarring Up and Jarring Down charts. Note, that in the jarring down section of the results table, any lines which are highlighted in orange, indicate the hook load range in which the string is modelled as being helically buckled. The buckling will occur at some point in the drill string above the jar and simply indicates that it may not be possible to transmit the required weight to cock / fire the jar. This range is represented in the jarring down chart by the red shaded area.
HKLD @ Fire: The surface hook load used to fire the jar This takes in to account the string weight and pick up forces which need to be overcome before the jar starts to have overpull applied. The calculation assumes CHFF 0.15 and OHFF 0.25.
OP @ Surf: The overpull registered at surface for a given hook load.
OP @ Jar: The overpull at the jar for a given hook load. This takes in to account the effects of drag.
Wt @ Surf: The weight registered at surface for a given hook load.
Wt @ Jar: The weight at the jar for a given hook load. This takes in to account the effects of drag.
Impact @ Jar: The impact at the jar resulting from the jar firing when the associated hook load is registered at surface. Calculated utilising the length of the drill collars above the jar, the stroke length of the jar, the overpull/weight applied and the drag in the hole.
Impulse @ Jar: The impulse at the jar resulting from the jar firing when the associated hook load is registered at surface. Calculated as the integral of impact force with respect to time.
Impact @ SP: The impact at the stuck point (the bit) resulting from the jar firing when the associated hook load is registered at surface. Calculated utilising the length of the drill collars above the jar, the stroke length of the jar, the overpull/weight applied, the drag in the hole and the distance between the jar and the stuck point.
Impulse @ SP: The impulse at the stuck point (the bit) resulting from the jar firing when the associated hook load is registered at surface. Calculated as the integral of impact force with respect to time.
Within the Jar Placement dialog, the user can output the following via the File Menu:
Jar placement report
The jarring results table data
Any of the charts present.
The user selects File > Print Report. This generates a report which can be saved to pdf format.
The report includes all the data and charts displayed within the Jar Placement dialog.
Exports the data in the Jarring Results table in a .txt file format.
Additionally, the user can export any of the charts individually using the right click context menu and selecting Export Dialog. For more information on exporting charts see Appendix A – Context Menu.
The settings Menu gives the user access to the Jar Placement Settings dialog.
The Jar Placement Settings dialog is where the user can adjust the jar check size and neutral point chart safety factors.
Jar Check Size: The user can enter the jar sizes and the relevant minimum and maximum hole sizes the jars are suitable to be run in. This information will be displayed on the main Jar Placement dialog in the jar checklist section. These sizes will also be used by the program for the Jar Size Check, where the user will be informed if the jar they have entered into the drill string is suitable, based on the hole size selected.
Neutral Point Safety Factors: The safety factors entered here are represented on the neutral point chart on the main Jar Placement dialog.
Safety factor 1 is represented by the red highlighted area
Safety factor 2 is the orange area displayed on either side of the neutral point line.
The default values are 5% and 10% respectively but can be changed here, as per the user’s requirements.
Impulse/Impact Charts X Axis Hookload: When checked, the X axis of the Jarring Up and Down charts will represent the Hookload at surface. If unchecked, the X axis will represent the relevant Overpull (Jarring Up) and Slack Off (Jarring Down) values.
The context menu is available in every plot by right clicking anywhere on the plot. This allows the user to change certain aspects of the plot based on their requirements. It should be noted that almost all of the functions available in this menu, are also available in the Chart Properties.
Viewing Style – Allows the user to select the desired Chart style.
Border Style – Allows the user to select the desired Border style of the chart.
Font Size – Allows the user to select the desired font size, which will affect all fonts on the chart including title and axis labels. Large, Medium or Small.
Plotting Method – Allows the user to select the way the line is plotted: Point, Line, Bar, Points + Line, Spline Area.
Data Shadows – Allows the user to select between off, shadow and 3D.
Grid Options – Allows the user to change the grid options in the chart.
Mark Data Points – Adds the data points relating to the data labels
Undo Zoom – Resets the zoom on the chart. Pressing the Z button has the same effect.
Maximise – Maximises the chart to fill the screen. Escape button exits this view.
Customization Dialog – Opens a dialog with more user definable chart options.
Export Dialogue – Allows the user to Export the chart using multiple image formats: EMF, WMF, BMP, JPG and PNG. The user has 3 options:
Clipboard: exports directly to clipboard, allowing images to be quickly added to word, excel & PowerPoint documents
File: Creates an image file of the chart which can be used on its own or imported into any suitable document
Printer: Sends the chart to the printer
The user can also choose the relevant Width, Pixels and DPI to use for the export. For Clipboard and File options, Pixels is the only available selection. When Printer is selected, the Millimeters, Inches and Points options become available to select.
A guide to the cementing module within Innova Engineering.
This document describes the cementing module within Innova Engineering and details the steps required to correctly utilise its functionality.
This document describes the cementing module within Innova Engineering and details the steps required to correctly utilise its functionality.
Units: Ensure that all units are correctly selected, based on requirements.
Options Menu – Cementing: The default flow rate in the Cementing tab is barrels per minute (bbls/min). This option allows the user to “Use flow units as pump rate”, which means the flow rate used in the cementing tab will match whatever the user has selected as the flow units from the units menu. This is useful when using the cementing section to simulate pumping pills etc.
To utilise the cementing modules functionality, the following inputs are required.
Drill String: Required inputs are component, description, OD, ID, TJ OD, TJ ID and length. Input the assembly as accurately as possible including the drill pipe to surface (note, for the last component e.g. DP to surface, the user does not have to input the exact length as the program will do this automatically based on the calculation depth. Inputting a nominal value of 10 is fine). Note that once a component type has been selected from the dropdown menu, it is possible to right click on the line and choose "select from Library", which will open the components library. The user can then select the appropriate component and select the option to insert it directly into the drill string grid.
Bit / Float TFA: If a float or bit has been included in the assembly, then it is important to enter the relevant TFA as this is required to calculate the pressure drop across this component, which is used in the pump pressure calculation. This is entered in the bit, casing or liner component details section.
Well Geometry: Input casing, liner, riser and open hole details including depths and ID's. For open hole, the ID is the same as the OD. Note that the user should only enter the well geometry which is relevant for the section in question and should not enter the entire casing string here.
Fluid Properties: Input mud weight, PV and YP. These inputs relate to the fluid in the wellbore prior to starting the cement job.
Survey Selection: Cementing calculations will be run using plan or survey data entered in the Survey Tab on the main user interface.
If there are well plan surveys and no actual surveys, the program will automatically use the well plan.
If there are actual surveys and no well plan surveys, the program will automatically use the actual.
If there are both well plan and actual surveys the program will use whatever is deeper.
Data is input as measured depth, inclination and azimuth in both the Actual Surveys and Well Plan sections, and the program will generate the rest of the numbers using whichever survey calculation method has been selected (Minimum Curvature Default). Cementing calculations are not run against surveys input in the RAW surveys table. The user can either enter the plan or surveys manually, import them or copy and paste the data directly into the cells.
This section displays the various volumes, capacities and displacements of the drill string and the annulus.
The top of this section details the different capacities of the drill string components. These components are taken directly from the drill string entered in the drill string tab, and the capacities are automatically calculated based on the dimensions (OD & ID) associated with these components. The annular capacities are detailed for the components, based on each of the lines entered in the Well Geometry section of the drill string tab. NOTE: A String Depth MUST be entered for this section to display correctly.
The middle part of this section shows the various capacities, volumes and displacements for the well. NOTE: A String Depth MUST be entered for this section to display correctly.
The lower part of this section is the most important as the inputs here affect the entire cementing calculations.
String Depth: Depth of the string when performing the cement job. The calculation will not run without a value entered here.
Displacement Type: Select Open Ended or Close Ended. This affects the Displacement and Total Displacement calculated values.
Flow Rate: Flow rate of cement job. This is used to calculate the Top Down, Bottoms Up and Full Circulation values. This input is not required to run the cementing calculation, as the pump rate for this is entered in the pumping schedule section.
Pump Output: Volume pumped per stroke. Pump efficiency should be factored into this input i.e. if the book output is 0.1bbl/stroke and the pump is 95% efficient, then output should be entered as 0.095bbl/stroke. This input is essential as it is required for calculating the number of strokes in the Pumping Schedule section.
Stroke Rate: This cell auto calculates based on the values entered for flow rate and pump output.
Hydraulics Model: Select from Bingham, Power Law, Herschel Bulkley or Robertson Stiff. This affects the calculated Annular Pressure, Pump Pressure and ECD values in the Cementing Results dialog.
This section allows the user to quickly calculate the volumes required for the cementing operation.
Row 1 should contain the first fluid to be pumped and the user can enter the required top, and the bottom will be automatically populated. The top and bottom depths of the fluid represent where they will be in the Annulus at the end of the cementing operations. The user can then enter as many additional lines as required. It should be noted that the bottom depth of the fluid in the last row will always be equal to the String Depth value input in the Volumes section.
The user can also enter the desired excess and the volume column will update automatically to reflect this excess percentage.
Once the Cement Volumes and Cement Job Calculation sections have been input, the user can select Create, which will populate the Pumping Schedule table, with the description and calculated volumes from the Cement Volumes section. Note that this also considers the data input in the Cement Job Calculation section. It is also possible to complete this section manually. In order for the schematic to be represented correctly in the results dialog, excess volume should not be included in this section.
If the Include Spacer box is checked and then Create is selected, row one of the table will be created for a spacer, but the volume cell will need to be populated manually by the user. If the user has included a spacer in the cement volumes section, then the include spacer box should not be checked.
The Use Rheometer Readings check box toggles the Pumping Schedule table between PV, YP and 600 – 3 rpm dial reading inputs.
The user should fill in the Description, Volume, Wt, Pump Rate, and rheology values for each row. These inputs affect the calculated Annular Pressure, Pump Pressure and ECD values in the Cementing Results dialog.
For conventional cement jobs the user should enter the Shoe – Float Distance. The shoe track capacity will be automatically calculated.
If cementing with a stinger, the user should check the Cementing with inner string box and enter the Description, OD, ID and Length of the stinger string. The capacity and total capacity of the inner string will be automatically calculated.
Once the cementing tab has been completed, selecting Calculate, opens the Cementing Results Dialog.
It is suggested that data is input in the following order to increase input efficiency. This is, however, just a guide and the user can enter the data in whatever sequence they wish.
Ensure units are correctly selected, including the cementing flow units in the Options menu.
Input data in the Drill String table. Input the component, description, OD, ID, length and TJ OD / ID if applicable (Drill String, Well Geometry & Fluids Tab).
Input any relevant TFA details in the Component details table (Drill String, Well Geometry & Fluids Tab).
Input the Well Geometry (Drill String, Well Geometry & Fluids Tab).
Input the drilling Fluid Properties (Drill String, Well Geometry & Fluids Tab).
Input the survey data into the Well Plan or Actual Surveys table (Surveys Tab).
Input the String Depth (Cementing Tab).
Select the Displacement Type (Cementing Tab).
Input the Flow Rate (optional) (Cementing Tab).
Input the Pump Output (Cementing Tab).
Select the Hydraulics Model (Cementing Tab).
Input the Description, Top and Excess % for each fluid in the Cement Volumes table (Cementing Tab).
Input the Shoe – Float Distance (Cementing Tab).
Add cementing inner string Description, OD, ID and Length if applicable (Cementing Tab).
If a spacer is being included and was not added in the cement volumes section check the Include Spacer checkbox (Cementing Tab).
Select the Create button in the Pumping Schedule section (Cementing Tab).
Input the Weight (Wt), Pump Rate, fluid rheology and spacer volume (if applicable) data (Cementing Tab).
Select the Calculate button to run the cementing calculation and open the Cementing Results dialog (Cementing Tab).
Once the user has entered all the required inputs, the user selects Calculate from the Cement Job Calculation section. This runs the cementing calculation and opens the cementing results dialog.
The Cementing Results dialog displays all the information and results relevant to the cementing module. By utilising the scroll bar at the bottom of the dialog the user can view the three charts at different stages of the cement job.
This is a visual representation of the well geometry, string and fluids at a given stage in the cement job, dictated by the position selected on the scroll bar. The values used to generate this schematic (MD, component OD & ID’s and well geometry OD & ID’s) are taken from the values entered in the Drill String, Well Geometry and Fluids Tab. The fluid labels can be toggled on or off by selecting Chart Options and checking or unchecking Show Schematic Fluid Labels.
Changes in well geometry are marked by a label and dashed line.
Areas out with the fluid flow path are white.
Sea water is dark blue
Drilling mud is brown.
Spacer is light blue.
Lead cement is dark grey.
Tail cement is light grey.
Displacement fluid is a variable colour.
The Pumping Schedule chart depicts:
The annular pressure at the string depth entered in the volumes section
The equivalent circulating density (ECD) at the string depth entered in the volumes section
The pump pressure at surface at a given stage in the cement job
The Flow Rate
All the above outputs are dictated by the position selected on the scroll bar.
The X-axis can be toggled to display either Elapsed Time or Strokes by selecting Chart Options and checking or unchecking X Axis – Strokes.
The position of the slider on the scroll bar dictates the stage of the cement job depicted on the Cementing Schematic, Pumping Scheldule and ECD Snapshot. The user can click the play button for the slider to commence movement at a specific speed. This speed can be adjusted using the + and – keys to speed up and slow down the slider progression respectively. The user can then select the pause button to stop the slider at any point. The slider can also be manually dragged to any point in the scroll bar by the user.
The ECD Snapshot chart depicts the equivalent circulating density and the annular velocity, across all depths from surface to the string depth, at a given stage in the cement job, dictated by the position selected on the scroll bar.
The right-hand side of the chart shows the flow regime across all depths from surface to the string depth, at a given stage in the cement job, dictated by the position selected on the scroll bar. Red is Laminar Flow and Green is Turbulent.
Additionally, markers display the respective depths of the top of the various fluids in the annulus and any changes in the well geometry.
Within the Cementing Results dialog, the user can output the following via the file menu:
PDF Cementing Report
Excel Cementing Report
Export Data
The user selects File > Print PDF Report. This generates a report which can be saved to pdf format.
The report includes all the relevant data used in the cementing calculation and the charts displayed within the Cementing Results dialog, as they appeared when the report was created.
The user selects File > Print Excel Report. This generates a report which can be saved to excel format.
The report includes all the relevant data used in the cementing calculation and the charts displayed within the Cementing Results dialog, as they appeared when the report was created. These charts are allocated their own sheet within the excel document.
This option allows the user to export the data used to generate the Pumping Schedule and ECD Snapshot Charts.
The context menu is available in every plot by right clicking anywhere on the plot. This allows the user to change certain aspects of the plot based on their requirements.
Viewing Style – Allows the user to select the desired Chart style.
Border Style – Allows the user to select the desired Border style of the chart.
Font Size – Allows the user to select the desired font size, which will affect all fonts on the chart including title and axis labels. Large, Medium or Small.
Plotting Method – Allows the user to select the way the line is plotted: Point, Line, Bar, Points + Line, Spline Area.
Data Shadows – Allows the user to select between off, shadow and 3D.
Grid Options – Allows the user to change the grid options in the chart.
Mark Data Points – Adds the data points relating to the data labels
Undo Zoom – Resets the zoom on the chart. Pressing the Z button has the same effect.
Maximise – Maximises the chart to fill the screen. Escape button exits this view.
Customization Dialog – Opens a dialog with more user definable chart options.
Export Dialogue – Allows the user to Export the chart using multiple image formats: EMF, WMF, BMP, JPG and PNG. The user has 3 options:
Clipboard: exports directly to clipboard, allowing images to be quickly added to word, excel & PowerPoint documents
File: Creates an image file of the chart which can be used on its own or imported into any suitable document
Printer: Sends the chart to the printer
The user can also choose the relevant Width, Pixels and DPI to use for the export. For Clipboard and File options, Pixels is the only available selection. When Printer is selected, the Millimetres, Inches and Points options become available to select.
A guide to the Casing Standoff output within Innova Engineering's Torque & Drag Module.
This document will deal with the Casing Standoff calculation within Innova Engineering's Torque & Drag Module and will detail the steps required to run this calculation.
The casing standoff calculation uses the data input by the user and calculates either:
The casing standoff based upon a given centralizer spacing entered by the user, or
The required centraliser spacing to achieve the users desired standoff. Based upon the minimum step value selected by the user the optimum centraliser spacing will also be calculated.
In order to run the casing standoff calculation, a Torque and Drag calculation needs to be run. For T&D setup, refer to the Torque & Drag Quick Start Guide.
Over and above the standard Torque & Drag inputs, the following inputs are required.
In the Tools Menu select - Standoff Optimisation Parameters
Desired Standoff: This is the standoff which will be calculated when Optimise Standoff is selected in the Torque and Drag section of the Engineering Parameters tab on the main user interface
Min Step Value: The minimum step value between one optimum spacing and the next. Engineering looks at the Required Spacing values which provide the desired standoff, and groups similar values (which land within the step range) together to provide a single Optimum Spacing output for each of these points. This is basically a smoothing parameter. Larger step values encompass more of the optimum spacing values providing more of a smoothing effect.
Max Spacing: The spacing value above which no centralisers will be recommended. This affects the Centralizer Spacing Summary in the Standoff Summary Report.
In the above charts the yellow line represents the Optimum Spacing and the pink line is the Required Spacing (achieves the Desired Standoff exactly). These examples show the difference in the Optimum Spacing when different minimum step values (5 and 100) are entered.
In the Options Menu, select Torque and Drag Model. If running bow spring centralizers, the user can select the option to Include Bow Spring Force within the torque and drag calculation. Note that if a bow spring force has been entered in the casing component details, this will be included in the casing standoff calculation regardless of what is selected here.
In the Drill String, Well Geometry & Fluids Tab, for each casing selected, in the component details, the user has the following centralizer inputs available:
Centralizer Spacing: The distance between Centralizers. If centralisers are only run across a certain interval, then the casing should be entered as separate sections in the string. NOTE: this value is ignored when Optimised Standoff is selected. This is a required input for the casing standoff calculation when Optimise Standoff is not selected.
Centralizer OD: The Outside Diameter of the Centralizer. For bowspring centralisers the OD input may be larger than the ID of the hole This is a required input for the casing standoff calculation.
Centralizer Length: The length of the centralizer blade which contacts the wellbore. This input is not used in the standoff calculation but is used for hydraulics.
Centralizer Blade Width: The width of the individual centralizer blades. This input is not used in the standoff calculation but is used for hydraulics.
Centralizer Blade Count: The number of blades on the stabilizer. This is not used in the standoff calculation but is used for hydraulics.
Bowspring Restoring Force: The Force exerted by a centralizer against the casing to keep it away from the wellbore wall. This input is used in the standoff calculation to determine how much the bow spring centralizer has deformed for a given side force. The centralizer will never compress more than the body OD. The higher the side force the more deformation of the centralizer. If nothing is entered for the restoring force it is assumed that the centralizer is rigid. In the scenario where the include bow spring force option is selected and the running force cell is left empty, this value will be used for the running force in the T&D calculation of the PU, SO and reaming values.
Centralizer body OD: The OD of the body of the centralizer. This is not used in the standoff calculation but is used for hydraulics. It is also used to calculate percentage compression of a bow spring stabiliser, which can affect the T&D results.
Running Force: The maximum force required to insert a centralizer into a specified wellbore diameter. This input is not used in the standoff calculation but is used for T&D. If entered, this value will supersede the bowspring restoring force in the T&D calculation. The running force will be applied to the pickup, slack-off and reaming values and will increase / decrease with the well bore size. Running force is not applied to the T&D calculation until the compression of the centralizer is greater than 50% and will gradually increase as the compression increases from 50% to 100%.
Centralizer Type: The user can manually enter the centralizer type and make / model here. This is not used in any calculations.
Running Force Restrict. ID: The restriction ID that 100% of the running force will be utilised in T&D calculation. When no value is entered here, the program will apply the running force to the T&D calculations based on the the amount of compression experienced by the bowspring centralizer at any given point in the wellbore. The more the centralizer is compressed, the higher the percentage of the running force which is applied. If the user enters a value here, the program will apply the maximum running force over any part of the wellbore where the ID is the same or less regardless of the compression.For example, Running Force = 2.1klbs, Running Force Restrict. ID = 8”. Any points in the well geometry that this component passes through with an ID less than or equal to 8” will have 2.1klbs of running force applied to the T&D calculation. Any part of the wellbore where the ID is greater than the value entered here will just be treated in the usual way.
In the Engineering Parameters tab the user can choose:
Optimise Standoff: This will override the centralizer spacing selected in casing component details, and output the spacing required to achieve the desired standoff
Point to Note: Optimised Standoff and Desired Standoff (in the Standoff Optimisation Parameters dialog) are linked. When the user changes the value in either of these boxes, it auto updates in the other.
In order to generate the Casing Stand Off output, the user must run a Torque & Drag calculation. To do this, select either the icon displayed below (low and high resolution icons), or select Calculate - Torque and Drag.
Once the calculation has been run, the Stand Off summary report can be viewed by selecting the TAD Results Menu and then Standoff Summary from the available options. This report can be saved as a pdf.
The Casing Standoff Chart is available by selecting the TAD Results Menu - Snapshot Charts - Casing Standoff.
The report can also be generated by selecting "File" - "Print Reports” or selecting the icon on the toolbar.
The three report options for Casing Stand Off can be found on the T&D tab at the bottom right:
Standoff Summary: This is the Report
Standoff Chart: A graphical representation of the results
Standoff Data: Base data used to generate the plots.
The report can be generated either as excel or pdf.
The standoff summary report is generated at the click of a button and contains the following:
Centralizer spacing summary
Drill string summary
Centralizer stand-off results
Standoff chart
Side forces / centralizer forces chart
Hookload chart
The casing standoff chart is a snapshot chart which provides outputs for each point in the string from surface to the calculated depth.
If Optimise Standoff has NOT been selected when the torque and drag calculation is run, the standoff chart will look like the above.
Inc: Inclination
Cent OD: Centralizer Outside Diameter
Deflection Mid Joint: Deflection of the casing between 2 centralizers.
Deflection Centralizer: Deflection of casing at the centralizer.
Standoff Mid Joint: This is calculated as follows (1 – (Deflection Mid Joint / ((Hole ID – Casing OD)/2))) * 100. It is effectively the percentage deflection from well bore centre. If the casing is centralised perfectly the standoff is 100%
Standoff Centralizer: The Percentage Standoff at the Centralizer. This is calculated as follows (1 – (Deflection Centralizer / ((Hole ID – Casing OD)/2))) * 100.
Cent Spacing: The centralizer spacing as entered by the user in the component details section of the drill string editor (This line will NOT be present if Optimise Standoff is selected in the Torque and Drag section of the Engineering Parameters tab on the main user interface).
Restoring Force: The restoring force of the bow spring centralizer which has been entered in the component details section of the drill string tab.
Running Force: The running force of the bow spring centralizer which has been entered in the component details section of the drill string tab.
Side Force: The side force exerted on the casing.
If Optimise Standoff has been selected (in the above this has been set at 60%), when the torque and drag calculation is run, the standoff chart will have the addition of an Optimum Spacing line, and the Centralizer Spacing line becomes the Recommended Spacing line.
Rec Spacing: Recommended Spacing, calculated based on the Optimise standoff value (This line will NOT be present if Optimise Standoff is not selected)
Opt Spacing: This is the optimum spacing which applies the maximum step value to the Recommended Spacing (This line will NOT be present if Optimise Standoff is not selected).
All the other lines described in Section 5.1.1 - Without Optimised Standoff, are also available to be displayed in this chart if required.
A guide to the SAG survey correction module in Innova Engineering
SAG occurs when a BHA bends under its own weight when positioned between two points of stabilisation. The degree of bending is affected by the hole size, stabiliser size, distance between points of stabilisation, and tubular OD & ID. SAG causes MWD sensor misalignment in relation to the borehole, and accounts for up to 80% of wellbore TVD position uncertainty.
The purpose of this document is to guide the user through the setup, calculation and the interpretation of the results of the SAG module in Innova Engineering.
Before inputting data, the user should configure the relevant options in the Units menu and the Options menu:
Units: Ensure that all of the units are correctly selected, based on your inputs.
Options – Include Motor Bend in BHA Analysis: This lets you toggle whether the program factors in the bend angle in your motor into the SAG calculation. See Section 7.2 for additional considerations when using this option.
Options – SAG Calculation Precision: This will let you set the number of decimal places that the SAG results will be calculated to. Default is 3.
In order to run SAG, the user is required to enter data into the Drill String, Well Geometry and Fluids Tab and the Surveys Tab.
In order to run SAG, the following parts of the Drill String, Well Geometry and Fluids Tab require data entered:
Well Geometry: The wellbore geometry tells the program the size of hole that the assembly is in.
Mud Weight: The mud weight is used to calculate the buoyancy of the drill string.
Drill string – All components: Enter your drill string into the Drill String section. This does not need to include any more than ~30m (100ft) of assembly beyond the last point of stabilisation. Beyond this point the remainder of the drill string will be lying on the low side of the hole and is not considered in the calculation. All components entered into the main Drill String table must have a component type, length, OD and ID. This includes items that don’t normally come with an ID, such as the motor or the bit.
Drill String – Stabilizers: As well as the above requirements, stabilizers require the following information entered into their component properties:
Stab OD: The outside diameter of the stabilizer.
Stab Blade Length: The length of the stabilizer blade that will be in contact with the side of the hole – Watch your units, this will be in inches or mm, depending on your diameter unit.
Stab Distance from Bottom: The distance from the Pin end shoulder to the bottom of the stab blade
Note: There is also space to enter stabilizer information into the component details for RSS, MWD/LWD, Motor, Turbine and Reamer component types. If you have stabilizer sleeves on any of these items in your BHA, don’t forget to enter the details for them as well.
Drill String – Motor Bend: If you have a motor in your BHA, you can enter the motor bend angle in the component details section. This is only required if you have the Include Motor Bend in BHA Analysis option toggled on.
In order to run SAG, the following parts of the Surveys Tab require data entered:
Survey Offset: The distance between the cutting surface of the bit and the MWD inclination sensor.
Select the type of SAG calculation that you want to run from the drop down box in the Survey Connections section. Users have a choice of Single, Inclination Range or Surveys. Single and Inclination Range are configured in the Survey Corrections section.
Selecting Single allows the user to calculate a SAG correction based on a single inclination:
Inc: Inclination that the user requires SAG results for.
DLS: Dogleg (°/30m or °/100ft depending on units selected). The program will use the dogleg to simulate hole curvature which affects the results. Zero represents a tangent.
TF: The Toolface of the motor bend during the survey. If the Include Motor Bend in BHA Analysis option toggled is toggled off, this will have no effect.
Selecting Inc Range allows the user to calculate SAG over a range of inclinations:
Inc Start: Initial Inclination.
Inc Stop: Final Inclination.
Inc Step: Step change in inclination between the initial and final. A step change of 2.5° will calculate SAG every 2.5° between the selected range.
DLS: Dogleg (°/30m or °/100ft depending on units selected). The program will use the dogleg to simulate hole curvature which affects the results. Zero represents a tangent.
TF: The Toolface of the motor bend during the survey. If the Include Motor Bend in BHA Analysis option toggled is toggled off, this will have no effect.
Selecting Surveys allows the user to calculate SAG on Actual Surveys, Well Plan Points or RAW Surveys, depending on what is selected. As well as the offset, the toolface of the motor is the only value in the Survey Corrections section that effects this calculation type. If the Include Motor Bend in BHA Analysis option toggled is toggled off, the TF will have no effect.
Select your survey type from the drop down box in the Survey Selection section, and then enter your surveys into the table. SAG can be run on Raw Surveys, Actual Surveys or Well Plan points. Whichever is selected in the Surveys tab when the calculation is run will be used.
Actual Surveys and Well Plan requires you to enter surveys using Measured Depth, Inclination and Azimuth. Raw Surveys require Measured Depth, raw Accelerometer Values (G) and raw Magnetometer Values (H). Make sure that you are using the correct units for your accelerometers and magnetometers.
To run the calculation, open the Calculate menu and select BHA Analysis and SAG Correction. The calculation will run and the results window will appear. You may also receive a warning. The most common warnings are:
WOB greater than zero, SAG correction value may be incorrect: The WOB parameter entered into the Engineering Parameters tab has an effect on the SAG result. Depending on your circumstances this may not be an error, but as surveys are usually taken when the bit is off bottom, the program will warn you if a value other than zero is entered.
No stabilizers: You have not entered any information in the component details for stabilizers, or components with stabilizer sleeves.
BHA tangential point found before sensor for 1 or more surveys: The tangential point is the point above the last stabilizer where the assembly touches the side of the hole. Anything above this point will be lying against the side of the hole and will therefore not be subjected to SAG. It is important to note that the tangential point changes depending on the curvature of the hole, and in some instances when running the calculation there will be some stations that will require correction and others that will not. Engineering runs through all of these calculations and assigns a 0° correction to those that do not. If you think you are getting this message in error, it is usually because you have set your survey offset too far back from the last stabilizer.
The following outputs are displayed in the SAG Results window:
Deflected Shape: Shows how far the BHA is from the centre line of the well bore. The X-Axis shows the distance from the bit along the BHA. The Y-Axis shows the deflection. The blue dot represents the sensor position. Note that the displayed plot always represents the final survey station.
BHA Slope: Shows the angle of the BHA with respect to the centre line of the well bore. The X-Axis shows the distance from the bit along the BHA. The Y-Axis shows the slope. The blue dot represents the sensor position, and the slope at this position is the error that is being corrected by the SAG correction. The displayed plot always represents the final station.
Below the charts is the results table, which contains the following information:
MD: Measured Depth of each survey station.
Inc (Org): The original uncorrected inclination of the survey.
Inc (Corr): The SAG corrected inclination.
Sag (Corr): The SAG correction to be applied to the uncorrected inclination to get the corrected inclination. Note that SAG correction is always added.
After running the calculation, the SAG column will be populated in the Survey tab and in the MSA window. Select SAG corrected Inc from the Inclination to Use drop down to use the corrected inclination when calculating the TVD, NS, EW and VS values.
A SAG report can be created with the following steps:
Close the results window. In the main Engineering interface, open the File menu and select Print Reports.
Configure your format and other options in the Options section.
Select the BHA Analysis and SAG type to create a SAG report. You can customize the report using the below options:
Before running the SAG calculation there are a couple of things to consider:
From 0-3° inclination the potential correction will likely be invalid due to the difficulty with finding the point at which the top of the BHA contacts the wellbore, this is due to the hole not having a defined highside.
Due to this, most companies have a policy that SAG should not be applied until the inclination is >3°. However, >5° is also acceptable in certain circumstances.
This consideration applies when using the Surveys calculation type.
If the motor bend is not being modelled in Engineering (Bend angle is 0° in the motor component details, or Include Motor Bend in BHA Analysis is turned off) then it is possible to SAG correct all required survey stations in one go. If however, the motor bend is being modelled, then each station has to be SAG corrected individually, assigning the relevant Toolface for each survey. This is more labour intensive and therefore more susceptible to errors.
When the bend is not being modelled, the addition of new stations has no effect on previous corrections. This is not the case when modelling the bend. When a new survey station is added and the correction run, the program runs the correction against all of the previous stations using the assigned toolface. Since every station will likely have been measured on a different toolface, it is possible that the program may change some of the previous corrections based on the new toolface. For this reason it is important to carefully note the correction at each new station as it is calculated, and understand why you may see a difference when looking at earlier corrections.
It is recommended that you try toggling the option on/off and comparing results. If there is a negligible difference, it may be simpler to leave the option off.
