Tubular

Class Usage Rules

Bent_Sub

Bit_Condition

Bypass_Sub

Casing

Casing_Accessory

Core_Barrel

Core_Bit

Cutter_Pty

Drill_Bit

Drill_Hole_Opener

Drill_Measurement_Tool

Drill_Motor

Drill_Pipe

Drill_Stabilizer

External_Casing_Packer

The external casing packer is run on the casing and expanded against the wall of the borehole at the proper depth by hydraulic pressure or fluid pressure from the well. External casing packers (ECP) are strictly pack off devices. There are no ports to the annulus or internal float valves. They are generally used below stage collars or port collars to protect the formation below from excessive hydrostatic pressure or contamination. They are also used in an attempt to block gas and fluid migration, and to provide positive centralization. ECP may be packed off by either inflating or compressing the rubber element. The inflatable type is generally larger and better capable of packing off oversized or irregular holes. The inflation process is generally set to begin at a predetermined setting pressure. The setting pressure should be sufficiently high to prevent premature pack off while conditioning or cementing. An optional break-off rod may be used to prevent a premature setting by blocking the inflation port until broken free by a wiper plug. Once the element is inflated, an internal valve mechanism will hold the inflated position, and the surface pressure may be released.

Generic_Tubular

Inflow_Control_Device

Jar

Motor_Pressure_Coef

Nozzle_Pty

Usage Rule for Nozzle_Pty

Case 1: All Nozzles of Same Diameter
At a given point of time, if all the nozzles are of same inside diameter, then there will be only one record of Nozzle_Pty. The count will be equal to the total number of nozzles.

The total flow area (TFA) will be computed using the inside diameter and count.

Case 2: Nozzles of Different Diameters
Count is the number of nozzles, ports, and jets with the SAME inside diameter. For example, if a drill bit, at a given point of time, has three nozzles (2x12/32", 1x13/32") then two Nozzle_Pty records will be instantiated; one with count 2 and the other with count 1 and respective inside diameters.

The flow area is computed for each record using the respective inside diameter and count. The total flow area will then be the sum of flow areas calculated for individual records.

Case 3: When No Nozzles are Used and TFA is Reported
Instantiate one record in Nozzle_Pty with count = 0 and store the total flow area. An example, of this case is when a drill bit is run without nozzles.

Case 4: Nozzles are Used and TFA is Reported Instead of Providing Nozzle Information with Inside Diameter and Count
Instantiate one record in Nozzle_Pty with count = -1 and store the total flow area. The negative number indicates that TFA is not computed.

Note: The above usage rule may be applied to nozzle, ports, or jets as the case may be.

Production_Packer

The production packer is usually made up in the tubing string, some distance above the producing zone. A packing element expands to prevent fluid flow except through the inside bore of the packer and into the tubing. Packers are classified according to configuration, use, and method of setting and whether or not they are retrievable (that is, whether they can be removed when necessary, or whether they must be milled or drilled out and thus destroyed).

R_Bit_Wear

R_Casing_Accessory

R_Casing_Accessory_Cat

R_Casing_Cat

R_Core_Barrel

R_Core_Bit

R_Cutter_Shape

R_Drill_Bit

R_Drill_Bit_Cat

R_Drill_Pipe_Cat

R_Generic_Tubular_Cat

R_IADC_Bearing_Seals

R_IADC_Grade_Dull

R_IADC_Grade_Location

R_IADC_Reason_Pulled

R_Inflow_Control_Device

R_Jar

R_Production_Packer

R_Production_Packer_Cat

R_Reamer

R_Slotted_Liner_Cat

R_Tubing_Cat

R_Tubular_Cat

R_Tubular_Grade

R_Tubular_Material

Reamer

Rotary_Cutting_Tool

Rotary_Steerable

Slotted_Liner

Tubing

Tubular

Tubular_Condition

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