MEGO AFEK Technical Manual 2013

Floating and Guiding Equipment

CASING EQUIPMENT | www.mego-afek.com

December 2, 2013

Floating equipment is commonly used on the lower

sections of the casing to reduce derrick stress by

allowing the casing to be floated into place. The weight

of the casing on holes of moderate to deep depths can

cause tremendous strain on the derrick. When the

casing is immersed in the well fluid, it is buoyed by force

equal to the weight of the fluid that the casing displaces.

If the casing is allowed to fill as it is lowered, the

buoyancy will be equal to the weight of the fluid

displaced by its wall. Should the casing not be allowed

to fill, a greater amount of fluid is displaced by the

casing string and the weight on the derrick is less.



The guide shoe directs the casing away from ledges

and minimizes sidewall caving as the casing passes

through deviated sections of the hole. Some basic

types of floating and guiding equipment are (1) the

guide shoe, with of without a hole through the

guide nose, (2) the float shoe containing float valve

and guide nose, and (3) the float shoe and float

collar containing and automatic fill-up valve.

The simplest guide shoe is an open-end collar, with

or without a molded nose. It is run on the first joint

of casing and simply guides the casing past

irregularities in the hole.

Circulation is established down the casing and

out the open end of the guide shoe, or

through side ports designed to create more

agitation as the cement slurry is circulated up

the annulus. If the casing rests on bottom or is

plugged with cuttings, circulation can be

achieved though the side ports.

A modified guide shoe with side ports may aid

in running the casing into a hole where

obstructions are anticipated. This tool has side

ports above and a smaller opening through

the rounded nose. The smaller opening

ensures that approximately one-half the fluid is

pumped through the existing side ports. These

ports will help wash away obstructions that

may be encountered and will also aid in

getting the casing to bottom if some of the

cutting have settled in the bottom hole.



When wells accumulate enough cuttings on the

bottom to cause a drop in pumping efficiency

and an increase in pumping pressure, a high side

port guide shoe can be installed on the casing

shoe to help remove these cuttings. This

equipment is particularly suitable to areas where

large accumulations of the cuttings make it

difficult to determine when casing touchdown is

accomplished. The jetting action of the side port

tool types aids in removing the cuttings and

helps provide a cleaner wellbore with increased

turbulence during circulation and cementing. It

can also aid in the uniform distribution of the

slurry around the shoe. If the casing is set on the

bottom and no fluid can exit through the bottom

of the tool, then the side ports can enable

circulation to be established.


The combination guide or float shoe usually

incorporates a ball or spring-loaded backpressure

valve. The outside body is made of steel of the

same strength as that of the casing.

The backpressure valve is enclosed in plastic and

high-strength concrete. The valve, which is closed

by a spring or by hydrostatic pressure from the

fluid column in the well, prevents fluids from

entering the casing while pipe is lowered into the

hole. Suspension is controlled by the volume of

fluid placed inside the casing by filling either from

the surface or through a fill-up device in the float

shoe. Once the casing has been run to the desired

depth, circulation is established through the casing

and float valve and up through the annulus.

When the cement job is completed, the

backpressure valve prevents cement from flowing

back into the casing.

For shallow wells where it is not necessary to guide

or float the casing to bottom, a simple casing shoe

is used. Float collars are normally placed one to

three joints above the float or guide shoe in the

casing string and serve the same basic functions

as the float shoe. They contain a backpressure

valve similar to the one in the float shoe and

provide a smooth surface or latching device for

the cementing plugs.

The space between the float collar and the guide

shoe serves as a trap for contaminated cement or

mud that may accumulate from the wiping action

of the top cementing plug. The contaminated

cement is thus kept away from the shoe, where the

best bond is required.

When the cement plug seats at the float collar, it

shuts off fluid flow and prevents over pumping o

the cement. A pressure buildup at the surface

indicates when cement placement is complete. For

larger casing, float collar or shoes may be obtained

with a special stab-in device that allows the cement

to be pumped through tubing or drill pipe.


(This method of placement is often called

inner-string cementing.) Such a device

eliminates the need for large cementing plugs

and oversize plug containers. It also reduces

the volume of cement that can be lost if the

job must be terminated before all the slurry is

mixed and pumped. For reason of economy,

simple insert flapper valve and seat may be

installed in the casing string one or two joints

above the guide shoe. This insert valve is

designed for use in wells down to 7,000 ft. and

for pressures less than the collapse pressure of

J-55 casing in the particular weight range

being used.

The backpressure valve in automatic fill-up

equipment is held out of service until it is

release by a predetermined pump pressure

or flow rate applied from the surface. The

rate of the flow into the casing is usually low

enough to hold the fluid level within 10 to

300 ft. of the surface.

The backpressure valve in automatic fill-up

equipment is held out of service until it is

release by a predetermined pump pressure

or flow rate applied from the surface. The

rate of the flow into the casing is usually low

enough to hold the fluid level within 10 to

300 ft. of the surface.

When purchasing floating equipment, it is

important to specify the OD, the threading,

the material grade, and the pipe weight.



Enclosed Down-Jet Special Nose Option

13

Al Aluminum


Tapered Down-Jet Special Nose Option

13

Al Aluminum


13

Al Aluminum

Tapered and Offset Round, Down-Jet Special Nose Option

Super Seal II®

Float Equipment Valve

The Super Seal™ II float collar includes the Super Seal™ II backpressure valve, which prevents cement pumped into the casing/wellbore annulus from re-entering the casing ID after cementing operations.

All casing-size Super Seal II® float collars

include an auto fill feature.

This feature, installed between the valve and pressure seat, is

deactivated by flow rate. The auto fill feature allows wellbore

fluids to enter the casing from the first joint, reducing surge

pressure on the formation and reducing casing fill time from

the surface. When the auto fill feature is pumped loose with a

high fluid rate, the float valve is returned to a dependable

Super Seal II backpressure valve. The auto fill feature will

deactivate if the flow through the valve reaches a

predetermined rate.

Manufactured in all common casing, weight and grade.


Super Seal II®

Collar & Shoe

Casing OD Casing Weight Tool OD Minimum ID Length Thread Type

in. lb./ft. in. in. in.

4 1/2

Different casing grades, weights, threads, valve configurations, and non-rotating valve

features are available. API® proprietary threading and PREMIUM threading available upon

request.

5

5 1/2

7

7 5/8

8 5/8

9 5/8

10 3/4

11 3/4

13 3/8

16

20


PDF™ (Pressure Differential Fill)

Float Equipment Valve

Pressure Differential Fill (PDF™) float collars and shoes allow

operators to maintain a constant fluid height inside the casing

of a well. As fluid is allowed to enter through the bottom of

the casing, the system maintains a constant differential

pressure between the inside and outside of the casing at the

floats to ensure constant fluid height within the casing.

PDF floating equipment is supplied in the differential fill mode

and is ready to be RIH. After all casing runs have been

completed, the differential fill option is deactivated by

dropping a weighted plastic ball from the surface and

pumping the ball through the tool.

Manufactured in all common casing, weight and grade.

A spring-loaded valve in the fill-up unit regulates filling. When

hydrostatic pressure outside the casing exceeds the spring

tension, fluid is allowed to enter the casing; when pressure

inside the casing combines with spring tension to exceed the

pressure outside the casing, the valve closes. The differential

pressure between the inside and outside of the casing is the

sum of the spring rates of all PDF floating equipment in the

casing string. The hole may be circulated at any time while

casing is run without affecting the fill-up unit. After the ball

passes the float collar and/or shoe, the PDF valve is converted

to a one-way cementing valve that allows cement to flow into

the annulus, where it is prevented from re-entering the casing.



PDF™ floating equipment should not be

used in wells deviated more than 30° from

vertical.


PDF™ equipment cannot be used with

Super Seal II™ floating equipment.

PDF™ (Pressure Differential Fill)

Collar & Shoe

Casing OD Casing Weight Tool OD Minimum ID Length Thread Type

in. lb./ft. in. in. in.

4 1/2

Different casing grades, weights, threads, valve configurations, features are available. API®

proprietary threading and PREMIUM threading available upon request.

5

5 1/2

7

7 5/8

8 5/8

9 5/8

10 3/4

11 3/4

13 3/8

16

20


Floating Equipment Specs

Super Seal II® Features - 2 ¼ in. valve in 2 7/8 in. through 4 in. equipment.

- 2 ¾ in. valve in 4 ½ in. equipment and larger.

- 4 ¼ in. valve in 7 in. equipment and larger.

- Single or double valve options in collars and shoes.

- Sealing sleeve for inner-string cementing operations with or

without latch down plug.

- Down-Jet and High-Port Up-Jet (HPUJ) float shoes.

- Non-rotating (NR) in 7 in. through 20 in. equipment.

- Tapered and offset tapered composite or aluminum noses.

- Centralized float shoes and collars.

PDF™ Features - Available in shoe and collar and can both be run in the same string if

needed.

- Reliable auto fill with casing circulation at any time, multiple times, during

pipe running procedures.

- Has a ball drop deactivation auto fill feature. After the ball passes the float

valve, the PDF flapper closes against its seat, preventing wellbore fluids or

cement from reentering the casing string.

- Standard 150 psi differential float valve spring. If more than one PDF valve

is run the psi is cumulative.

- Maintains a constant fluid height inside the casing.

- PDF should not be used on wellbores greater than 30 degree deviation.



Well Casing & Liner Type Size (OD, in.) Setting Depth (ft.) Function

Stabilizes collar and protects rig foundation.

Restrains unconsolidated formations.

Confines circulating fluids.

Helps prevent water flow and loss of circulation.

Helps prevent contamination of freshwater

zones.

Connects blowout preventer and wellhead.

Supports deeper casing and tubing string.

Confines shallow zones and prevents loss of

circulation.

Helps prevent sloughing and enlargement of

hole during deeper drilling.

Protects production string from corrosion.

Helps to resist high formation pressure.

Protects against loss of drill string in key-seated

or “sticky” holes.

Helps prevent loss of circulation.

Conductor Casing

Surface Casing

Intermediate Casing

20 to 36

7 to 20

7 to 11 3/4

40 to 1,000

to 4,500

Production Casing 2 3/8 to 9 58

Varies with hole

conditions

Through

production zone

Protects hole.

Isolates fluids and prevents fluid migration.

Helps provide well control if tubing fails.

Protects down hole equipment.

Allows selective production of oil an gas.

Functions like production casing.

Limits need for full string of casing.

Through

production zone

5 to 7 Liner

Cementing Plugs


Unless a well is drilled with air or

gas, the casing and hole are

usually filled with drilling fluid

before cementing. To minimize

contamination of the interface

between the mud and the cement

in the casing, a bottom plug is

pumped ahead of the cement

slurry. This plug wipes the mud

from the casing wall as it moves

down the pipe. When it reaches

the float collar, differential

pressure ruptures a diaphragm on

top of the plug, allowing the

cement slurry to flow through the

plug and the floating equipment

and up the annular space between

the pipe and the hole.


The top cementing plug is landed

at the float collar or float shoe.

It keeps the displacement fluid

from channeling with and

contaminating the cement slurry

and cause a pressure buildup in

the pipe.

Although top and bottom plugs

are similar in outward

appearance, their internal

structures are different. The top

plug, with its drillable insert and

rubber wipers, is built to

withstand the force of the cement

column and displacement fluid

and to provide dependable

sealing or shutoff when it lands

on a collar, baffle plate, or shoe.


The bottom plug is fitted with a diaphragm in its top that

will rupture at about 200 to 400 psi, thereby allowing the

cement to be pumped through the floating equipment,

down the casing, and into the annular space. The burst

pressure of the diaphragm is high enough to prevent

premature rupture before the plug lands. The bottom

plug usually molded out of a different color so that the

top plug may be readily distinguished from the bottom

plug. For cable tool operations, plugs are made with

plastic inserts to reduce drilling time.

There are times when a bottom plug is not desired. In

these cases, water or chemical flush should precede the

cement slurry to clean the casing of the mud solids. This is

not as effective as the mechanical wiping action of the

bottom plug, but it will reduce the amount of

contaminated slurry. The top plug follows the cement

slurry, wiping it from the casing wall.


Wiper Plugs

Five Wiper is designed to provide fluid separation during displacement and

wiping efficiency for wiping wellbore casing and tubular clean of

drilling mud, spacers, and cement.


Wiper Plugs

Non-Rotating

Five Wiper plugs have added locking teeth that prevent the equipment

from spinning during drill out, which reduces drill out times and

associated rig costs.

Wiper Plugs

HWE® (High Wiping Efficiency) top and bottom cementing plugs are designed to help improve wiping

efficiency during cementing operations.

The wipers of the HWE plug are a deep-cup design, which provides

greater wiping efficiency to remove mud cake, mud film, rust, and mill

scale.


Casing OD Casing Weight Length OD ID

in. in. in. in. in.

3 1/2 07.70 to 12.95 5.180 3.240 1.900

4 1/2 09.50 to 15.10 9.120 4.350 2.540

5 11.50 to 18.00 9.120 4.840 2.870

5 1/2 13.00 to 23.00 9.120 5.310 3.270

7 17.00 to 32.00 9.120 6.750 4.450

7 5/8 20.00 to 39.00 9.100 7.330 5.000

9 5/8 29.30 to 53.50 9.120 9.250 6.910

10 3/4 32.75 to 65.70 10.000 10.370 8.000

11 3/4 38.00 to 60.00 10.600 11.330 9.360

13 3/8 48.00 to 72.00 12.250 12.940 9.930

16 65.00 to 118.0 17.540 15.400 11.680

18 5/8 87.50 to 115.0 21.920 19.500 14.950


Five Wiper Plugs

Non-rotating five wiper plugs are available for casing 7 in. to 20 in. only.

Five wiper plugs are available for WBM, OBM, and SBM systems.

Available top and bottom plastic and aluminum insert bodies.

Bottom plugs have a 350 psi rupturable diaphragm.

Casing OD Wiper OD

Min. ID for Plastic Five Wiper Plugs, NR Plugs,

and Bottom Aluminum Plugs

in. in. in.

3 1/2 3.240 2.950

4 1/2 4.350 3.810

5 4.840 4.050

5 1/2 5.310 4.490

7 6.750 5.870

7 5/8 7.330 6.450

9 5/8 9.250 8.400

10 3/4 10.370 9.550

11 3/4 11.330 10.420

13 3/8 12.940 12.070

16 15.400 13.500

18 5/8 19.500 -


Minimum Casing IDS For Five Wiper Plugs


HWE® (High Wiping Efficiency)

Plugs

Casing OD Casing Weight Min. / Max. ID Length OD ID

in. in. in. in. in. in.

4 1/2 09.50 to 15.10 03.65 / 04.09 8.75 4.390 2.630

5 11.50 to 18.00 03.83 / 0456 8.75 4.940 2.630

5 1/2 13.00 to 23.00 04.38 / 05.04 8.75 5.344 3.220

7 17.00 to 32.00 05.66 / 06.54 9.00 6.788 4.414

7 5/8 20.00 to 39.00 06.24 / 07.13 9.00 7.375 5.000

9 5/8 29.30 to 53.50 08.16 / 09.06 9.00 9.313 6.939

10 3/4 32.80 to 65.70 09.09 / 10.19 10.00 10.336 7.980

13 3/8 48.00 to 72.00 11.79 / 12.72 12.25 12.965 10.620 HWE® plugs are available for WBM, OBM, and SBM systems.

New rubber and phenolic plastic designs offer increased drill out benefits with smaller debris, tighter

gripping, and easier drill out than five wiper plugs.

HWE® plugs are suitable up to 400° F.

The bottom plug is supplied with a 750 psi rupture disk.

Casing Centralizers



The uniformity of the cement sheath

around the pipe determines to a great

extent the effectiveness of the seal

between the wellbore and the casing.

Since holes are rarely straight, the pipe will

generally be in contact with the wall of the

hole at several places. Hole deviation may

vary from zero to -in offshore directional

holes- as much as 70° to 80°. Such severe

deviation will greatly influence the number

and spacing of centralizers. A great deal of

effort has been expended to determine

the relative success of running casing

strings with and without centralizers.

Although authors differ about the proper

approach to an ideal cement job, they

agree unanimously that success hinges on

the proper centralization of casing.

Centralizers are among the few

mechanical aids covered by API

specifications.

When properly installed in gauge sections

of a hole, centralizers prevent drag while

pipe is run into the hole, center the casing

in the wellbore, minimize differential

sticking, and thus help to equalize

hydrostatic pressure in the annulus, and

reduce channeling and aid in mud removal.

Two general types of centralizers are

spring-bow and rigid. The spring-bow type

has a greater ability to provide a standoff

where the borehole is enlarged. The rigid

type provides a more positive standoff

where the borehole is to be gauged.

Special close-tolerance centralizers may be

used on the liners. The important design

considerations are positioning, method of

installation, and spacing. Centralizers

should be positioned on the casing through

intervals requiring effective cementing, on

the casing adjacent to (and sometimes

passing through) the intervals where

differential-sticking is a hazard, and

occasionally on the casing passing through

doglegs where key seats may exist.


Another type uses spiral pins driven between the clamp and the casing to

supply the holding force. Other have dogs (or teeth) on the inside that

actually bite into the casing. Any clamp that might scar the surface of the

casing could be considered unusable where corrosion problem exist. One of

the little-emphasized benefits of centralizers is that they reduce pipe sticking

caused by pressure differentials. The force holding casing against a

permeable section in the hole is proportional to the pressure differential

across the pipe and to the area of the pipe in contact with the wellbore

isolated from the hydrostatic pressure by thickened mud cake.

The design of centralizers varies considerably, depending on the purpose

and the vendor. For this reason, the API specifications cover minimum

performance requirements for standard and close-tolerance spring-bow

casing centralizers. They are not applicable to rigid or positive centralizers.


Effective cementing is important through the production intervals and

around the lower joints of the surface and intermediate casing strings to

minimize the likelihood of joint loss. The centralizers are held in their relative

position on the casing by either the casing collars or mechanical stop collars.

The restraining device (collar or stop collar) should always be located within

the bow-spring-type centralizer so the centralizer will be pulled - not pushed

- into the hole. Therefore, the bow-spring-type centralizer should not be

allowed to ride free on a casing joint. All casing attachments should be

installed or fastened to the casing by some method, depending on the type-

i.e., solid body, split body, or hinged. If they are not installed over a casing

collar, then a clamp must be used to secure or limit the travel of the various

casing attachments.

There are a number or different types of clamps. One type is simply a friction

clamp that uses a set screw to keep the clamp from sliding.


Standard Suited for vertical applications, the standard has been in use for

nearly 30 years and is manufactured to API 10D specification

ensuring this centralizer consistently provides superior

performance.

Bow Spring Centralizer

Standard with Turbo Fins has turbo fins designed to deflect the fluid flow in a turbulent

and outward directed spiral.

Manufactured in all common casing and hole size combinations.

Casing OD Hole ID ID OD Height Bows

in. in. in. in. in. no.

3 1/2 6 3 1/2 6 22 3/4 4

3 1/2 6 1/8 3 1/2 6 1/8 22 3/4 4

3 1/2 6 1/4 3 1/2 6 3/4 22 3/4 4

4 1/2 6 4 1/2 6 1/2 22 1/2 4

4 1/2 6 1/8 4 1/2 6 1/8 23 4

5 1/2 6 3/4 5 1/2 7 23 4

7 8 1/2 7 9 1/2 22 3/4 4

7 5/8 9 7/8 7 5/8 10 1/2 23 6

7 5/8 9 1/2 7 5/8 10 23 6

9 5/8 12 1/2 9 5/8 13 23 6


Bow Spring Standard & Standard with Turbo Fins



9 5/8 12 1/4 9 5/8 13 22 1/2 6

9 7/8 12 1/4 9 7/8 12 3/8 22 3/4 6

10 3/4 12 1/4 10 3/4 13 1/4 23 6

10 3/4 14 3/4 10 3/4 14 3/4 23 6

11 3/4 14 3/4 11 3/4 14 3/4 22 3/4 6

13 3/8 17 1/2 13 3/8 18 1/2 22 6

13 5/8 17 1/2 13 5/8 18 1/2 22 6

16 18 1/2 16 18 1/2 23 8

16 22 16 22 22 3/4 8

20 26 20 26 26 10


Bow Spring Standard & Standard with Turbo Fins


Bow Spring Centralizer

Semi Rigid Centralizer

Close Tolerance is a liner centralizer designed for close tolerance applications

where running drag must be minimized paired with highest

possible centering strength.

Dual Contact is ideal for highly deviated and horizontal applications.



in. in. in. in. in. No.

3 1/2 4 3/4 3 11/16 4 3/4 23 4

4 1/2 7 4 11/16 7 1/2 23 4

5 6 1/8 5 1/4 6 1/4 22 1/2 4

5 1/2 6 1/2 5 11/16 6 5/8 23 4

7 8 1/2 7 1/4 9 1/2 22 1/2 4

7 5/8 8 1/2 7 13/16 8 3/4 23 4

7 5/8 8 1/2 7 13/16 8 5/8 23 4

9 5/8 10 5/8 9 13/16 10 7/8 23 6

9 5/8 12 1/4 9 7/8 13 22 1/2 6

9 7/8 12 1/4 10 1/16 12 3/4 23 6

16 20 16 1/4 22 1/2 22 1/2 8

22 28 22 1/4 29 22 1/2 12


Bow Spring Close Tolerance

Semi Rigid Dual Contact



4 1/2 6 1/8 4 5/8 6 1/4 25 1/2 4

5 7 7/8 5 1/8 8 25 1/2 4

5 1/2 8 1/2 5 5/8 8 1/2 25 1/2 4

5 1/2 8 3/4 5 5/8 8 5/8 25 1/2 4

7 8 3/8 7 1/8 8 5/8 25 1/2 4

7 8 1/2 7 1/8 8 3/4 25 1/2 4

7 9 7/8 7 1/8 10 25 1/2 4

7 5/8 9 7/8 7 3/4 9 7/8 25 1/2 4

9 5/8 12 1/4 9 3/4 12 5/8 25 1/2 6

9 7/8 12 1/4 10 12 1/8 25 1/2 6

10 3/4 12 1/4 10 7/8 12 1/2 25 1/2 6

10 3/4 13 1/2 10 7/8 13 3/4 25 1/2 6

10 3/4 14 3/4 10 7/8 15 1/4 25 1/2 6

13 3/8 16 13 1/2 16 3/8 25 1/2 6

13 3/8 17 1/2 13 1/2 17 3/4 25 1/2 6

13 5/8 16 13 3/4 17 5/8 25 1/2 6

14 16 14 1/8 16 1/8 25 1/2 8

20 24 20 1/8 25 1/2 25 1/2 8


Rigid Centralizer

Positive Bar provides positive standoff and centering, and can be used in both

cased or open hole applications. Designed for use in highly

deviated and horizontal well conditions, and offers sufficient

clearance for fluid passage, maximum flow and well bore

stabilization.

Turbo can be used in deviated and vertical

well applications, where wellbore

fluid turbulent flow is required.


Casing OD Hole ID OD ID Height Bows

in. in. in. in. in. No.

2 7/8 3 1/2 3 1/4 3 14 4

2 7/8 3 7/8 3 7/8 3 14 4

3 1/2 6 6 3 5/8 14 4

4 1/2 5 7/8 5 7/8 4 5/8 14 4

5 5 7/8 5 7/8 5 1/8 14 4

5 6 1/4 6 1/4 5 1/8 14 4

5 7 3/8 7 3/8 5 1/8 14 4

5 1/2 6 1/2 6 ½ 5 5/8 14 4

7 8 1/4 8 ¼ 7 1/8 14 6

7 5/8 9 1/4 9 ¼ 7 3/4 14 6

9 5/8 12 12 9 3/4 14 6

9 7/8 12 12 10 14 6

10 3/4 14 1/2 14 ½ 10 7/8 14 8

11 3/4 14 1/2 14 ½ 11 7/8 14 8

13 3/8 17 1/4 17 ¼ 13 1/2 14 8

16 19 1/2 19 ½ 16 1/8 14 8

16 21 1/2 21 ½ 16 1/8 14 8

20 25 25 20 1/8 14 8


Rigid Positive Bar


Stop Collar

Friction will provide the sliding limits according to API RP 10D-2.

FASGRIP™ with dogs design with case hardened inserts embedded in collar

ID to provide maximum holding resistance.

Slip-On offers superior holding capability in close tolerance

conditions and where extreme loading may occur.

20,000 lbs.

40,000 lbs.

7,000 lbs.



Stop Collar Friction

Casing OD Hole ID Screw Holding Force up

in. in. in. lb.

2 7/8 4 3/8 3/8 x 2 3/4 7,000

3 1/2 5 3/8 x 2 3/4 7,000

4 1/2 6 3/8 x 2 3/4 7,000

5 6 1/2 3/8 x 2 3/4 7,000

5 1/2 7 3/8 x 2 3/4 7,000

7 8 1/4 3/8 x 2 3/4 7,000

7 5/8 9 1/8 3/8 x 2 3/4 7,000

9 5/8 11 1/8 3/8 x 2 3/4 7,000

9 7/8 11 3/8 3/8 x 2 3/4 7,000

10 3/4 12 1/4 3/8 x 2 3/4 7,000

11 3/4 13 3/4 3/8 x 2 3/4 7,000

13 3/8 14 3/4 3/8 x 2 3/4 7,000

16 17 3/8 3/8 x 2 3/4 7,000

20 21 1/2 3/8 x 2 3/4 7,000


Stop Collar FASGRIP™

Casing OD Hole ID Screw Holding Force Up

in. in. in. lb.

2 7/8 4 3/8 3/8 x 2 3/4 40,000

3 1/2 5 3/8 x 2 3/4 40,000

4 1/2 6 3/8 x 2 3/4 40,000

5 6 1/2 3/8 x 2 3/4 40,000

5 1/2 7 3/8 x 2 3/4 40,000

7 8 1/2 3/8 x 2 3/4 40,000

7 5/8 9 1/8 3/8 x 2 3/4 40,000

9 5/8 11 1/8 3/8 x 2 3/4 40,000

9 7/8 11 3/8 3/8 x 2 3/4 40,000

10 3/4 12 1/4 3/8 x 2 3/4 40,000

11 3/4 13 1/4 3/8 x 2 3/4 40,000

13 3/8 14 7/8 3/8 x 2 3/4 40,000

16 17 1/2 3/8 x 2 3/4 40,000

20 21 1/2 3/8 x 2 3/4 40,000


Stop Collar Slip On

Casing OD Hole ID Screw Holding Force Up

in. in. in. lb.

3 1/2 4 3/4 3/8 x 13 20,000

5 6 1/4 3/8 x 13 20,000

5 1/2 6 3/4 3/8 x 13 20,000

7 8 1/4 3/8 x 13 20,000

7 5/8 8 1/2 3/8 x 13 20,000

9 5/8 10 7/8 3/8 x 13 20,000

9 7/8 11 1/8 3/8 x 13 20,000

13 3/8 14 5/8 3/8 x 13 20,000

16 17 1/4 3/8 x 13 20,000

22 23 1/4 3/8 x 13 20,000

MEGO AFEK USA Hidalgo, Texas

+1 (956) 843-2289

[email protected]

MEGO AFEK MEX Reynosa, Tamaulipas

+52 (899) 923-5013

+52 (899) 923-5014

[email protected]

Poza Rica, Veracruz

+52 (782) 111-0305

[email protected]

MEGO AFEK VEN Maracaibo, Zulia

+58 (261) 732-0757

+58 (261) 731-3820

+58 (261) 731-1223

MEGO AFEK Technical Manual 2013

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Transcript of MEGO AFEK Technical Manual 2013