Drilling calculations handbook

This lets you create realistic, multiple design options in one session. How do you print the wellbore diagrams? I can't seem to find a print icon or menu anywhere in this program.

There is no print feature in the i-Handbook. However, if you right-click on the wellbore diagram as well as in most of the i-Handbook pages , you'll be able to copy the page content. You can then "paste" what you've just copy in any Windows application that accepts pictures, like Word, WordPad, Excel, and Powerpoint.

You can add your own annotation, add a title and date, and then print from there. When you are in the tubing or casing sections, just click on the little page icons bottom left to show the additional pages. It contains the Drift Diameters Drift Dia. Can I install the i-Handbook on different computers?

Can I copy the i-Handbook and give it to friends? Yes, you can install the i-Handbook on different computers. You can also copy and give the i-Handbook to friends, but you are not allowed to sell it. However we encourage you to get the full version and to sign up to be informed when new versions will be released.

This is an issue with the demo version of the i-Handbook when display settings use large fonts. You can fix the problem by changing your display settings to use small fonts. To install i-Handbook, you will need administrator privileges on your computer and will need to run the installer as an administrator. Right click on the i-Handbook. The default installation option of i-Handbook is to start automatically when you start Windows.

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You can either create a rule in your virus scan tool to enable the auto start for i-Handbook. Or, alternatively, you can uninstall i-Handbook and install it again without the auto start option. You can still pin it to the Taskbar for quick access. Premium content requires special account permissions. We need a little more information from you before we can grant you access. The electronic version of the Field Data Handbook. Download File. Contact Us. Related Documents.

Register to Learn More. Weighted Cement Calculations 9. Calculations for the Number of Sacks of Cement Required Calculations for the Number of Feet to Be Cemented Setting a Balanced Cement Plug Hydraulicing Casing Depth of a Washout Lost Returns Loss of Overbalance Stuck Pipe Calculations Calculations Required for Spotting Pills Pressure Required to Break Circulation.

Chapter 3 Drilling Fluids P. Increase Mud Weight 2. Dilution 3. Mixing Fluids of Different Densities 4. Oil Based Mud Calculations 5. Example: Example: 1. Example: 0. Hydrostatic pressure using ppg and feet as the units of measure. Pump Output P0 4. Rod diameter 2. Drill pipe OD 2. ID, in. Determination of exact factor in above equation The above formula is an approximation because the factor Dp, in. Slug Calculations.

Example: Determine volumes and strokes for the following: Step 1 Hydrostatic pressure required to give desired drop Drill pipe 5. The pressure must not OD3 in. Cuttings must be washed free of mud. Set mud balance at 8.

Move counterweight to obtain new balance. The following will be determined: b Maximum length of drill pipe that can be run into the Length of bottom hole assembly BHA necessary for a hole: desired weight on bit WOB. These include: drilling stopped before coming out of hole. Round trip ton-miles 2. Coring ton-miles 4. Bentonite LA-2 Latex 0. Weighted Cement Calculations.

Cement program: LEAD cement Example: From the data listed below determine the following: Calculations for the Number of Feet to Be Cemented 1. How many sacks of LEAD cement will be required? How many sacks of TAIL cement will be required? If the number of sacks of cement is known, use the following: 3.

How many barrels of mud will be required to bump the plug? Step 1 Determine the following capacities: 4. How many strokes will be required to bump the top plug?

Setting a Balanced Cement Plug. Dp in. Example: From the data listed below, determine the Height, ft, of the cement in the annulus casing: 3 2.

Depth, ft, of the top of the cement in the annulus Dh, in. Number of barrels of mud required to displace the cement 3 5. Drill pipe 5. Use 1. The 3 Example 1: A ft plug is to be placed at a depth of ft. Number of sacks of cement required 1. Determine the hydrostatic pressure exerted by the cement 2.

Volume of water to be pumped behind the slurry to balance and any mud remaining in the the plug annulus. Plug length before the pipe is withdrawn 2. Determine the hydrostatic pressure exerted by the mud 4. Amount of mud required to spot the plug plus the spacer and cement remaining in the casing. Determine the differential pressure. These calculations will determine if the casing will hydraulic Determine the area, sq in.

Determine the Upward Force F , lb. This is the weight upward. Equivalent mud weight at TD. Table Pump some material that will go through the washout, up the Drill Pipe Stretch Table annulus and over the shale shaker. This material must be of the type that can be easily observed as it comes across the shaker.

Examples: carbide, corn starch, glass beads, bright ID, in. Nominal ID, in. Wall Area, coloured paint, etc. Step 5 Determine strokes required to pump pill:. Chenevert, Martin E. Therefore, approximately 94 psi would be required to break circulation. Pressure required to overcome the muds gel strength in the annulus. Increase Mud Density Mud weight increase with calcium carbonate SG 2. Example: Determine the starting volume, bbl, of Example: Determine the number of barrels of water weighing Determine the density and volume when the two following 8.

Oil Based Mud Calculations. Obtain the percent-by-volume oil and percent-by-volume As in Example I, there are 68 bbl of liquid in bbl of this water from retort analysis or mud still analysis. From the data mud.

For low chloride muds to be decreased, add water. The total liquid volume will be increased by the volume of the oil added, but Step 4 Average specific gravity of solids ASG the water volume will not change. Dilution of Mud System. Dilute with 9. Example: bbl in mud system. References 1. Crammer Jr.

Drill String Volume. Example: 50 psi: Final circulating pressure FCP The pressure side of the chart will be as follows:. Pressure Chart. Step 3 Determine interim pressure for 5. Adjust the strokes as necessary. Note: Whenever a kick is taken with a tapered drill string in the hole, interim pressures Figure Data from kill sheet. After pumping strokes, if a straight line would large drill pipe plus the length of small drill pipe.

Example: Drill pipe 1: 5. The ft x 0. Hydrostatic pressure increase from surface to KOP: Using a regular kill sheet, the circulating drill pipe pressure would be psi. Note: At this point, compare this circulating pressure to the value obtained when using a regular kill sheet.

Adjusted pressure chart. Drill pipe Precautions to be undertaken before testing:. Step 1 Determine fracture pressure, psi: 1. Shut-in the well. Monitor pressure, time, and barrels pumped. Some operators may have different procedures in running this test, others may Method 2: Use when assuming the maximum pressure in include: the wellbore is attained when the formation at the shoe a.

Some operators prefer not pumping against a Note: A safety factor is added to ensure the formation closed system. They prefer to circulate through the fractures before BOP pressure rating is exceeded. In this method, the annular pressure loss Step 2 Determine the hydrostatic pressure of gas in the should be calculated and added to the test pressure wellbore HPgas : results. Determine diverter line inside diameter, in. Diverter line ID, in. Test mud wt, x 0. Example: Determine the maximum surface pressure, psi, 2 Determine the estimated fracture gradient from a Fracture using the following data: Gradient Chart.

Base Mud. Determine pressure exerted by influx at TD: 3. Determine T R at TD and at shoe:. Determine A: Determine A: the wellbore, psi.

Example: Oil bearing sand at 12, ft with a formation Minimum Surface Pressure Before Stripping is Possible pressure equivalent to If the specific gravity of the oil is 0. Determine formation pressure, psi: Example: Drill collars 8.

Example: If ft of 5. While 0. Step 2 Correct internal yield pressure for safety factor. Some 1. The Bullheading method of killing a well is primarily used in the following situations: Plot these values as shown below:.

No communication exists between tubing and annulus. Influx in the casing. Bullheading is simplest, fastest, and safest method to use to kill the well. Using the information given below, the necessary calculations will be performed to kill the well by bullheading. The example calculations will pertain to a above:. Tubing pressure profile. NOTE: Determine the best pump rate to use.

The pump rate Lubricate and Bleed must exceed the rate of gas bubble migration up the tubing. The data below will be used to describe this Grayson, Richard and Fred S. Services, Houston, Texas. Milchem Well Control, Houston, Texas Rig up all surface equipment including pumps and gas flare lines.

Open the choke to allow gas to escape from the well and momentarily reduce the SITP. Close the choke and pump in 9. Wait for a period of time to allow the brine to fall in the tubing.

Open the choke and bleed gas until 9. Continue the process until a low level, safe working pressure is attained. A certain amount of time is required for the kill fluid to fall down the tubing after the pumping stops. The actual waiting time is not to allow fluid to fall, but rather, for gas to migrate up through the kill fluid. Therefore considerable time is required for fluid to fall or migrate to ft. Therefore, after pumping, it is important to wait several minutes before bleeding gas to prevent bleeding off kill fluid through the choke.

To determine nozzles, 32nd in. Example: Optimize bit hydraulics on a well with the following:. Select the proper jet sizes for impact force and hydraulic horsepower for two jets and three jets:. Nozzle area, sq in. Bit nozzle pressure loss, psi Pb : x 2 2 nozzle area, sq in.

Total pressure losses except bit nozzle pressure loss Pc , psi: 5. For optimum flow rate Qopt : log To determine nozzle area, sq in. Determine pressure losses at the bit Pb : accurately analyze various parameters of existing bit hydraulics. Determine nozzle area, sq in. Nozzles area, sq. Hydraulic horsepower per square inch of bit diameter: 2 x Determine nozzle size, 32nd in. Impact force, lb, at bit IF : IF. Determine nozzles, 32nd in. Hole size 5. The d exponent is influenced by mud weight variations, so modifications have to be made to correct for changes in mud 2.

Cuttings Slip Velocity MW 0. These calculations give the slip velocity of a cutting of a Nomenclature: specific size and weight in a given fluid. The annular velocity and the cutting net rise velocity are also calculated.