10. downhole cementing equipment
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Section 10
Downhole CementingEquipment
Table of Contents
Introduction..............................................................................................................................................10-3
Topics...................................................................................................................................................10-3
Learning Objectives ............................................................................................................................. 10-3
Unit A: Guiding and Floating Equipment................................................................................................10-3
Guide Shoes..........................................................................................................................................10-3
Super Seal II Float Shoe...................................................................................................................10-4
Super Seal II High-Port Up-Jet (HPUJ) Float Shoe ......................................................................... 10-4
Super Seal II Down-Jet Float Shoe ..................................................................................................10-5
Super Seal II Float Collar.................................................................................................................10-5
Insert Flapper Float Valve....................................................................................................................10-6
Backpressure Valves ............................................................................................................................ 10-6
Pressure Differential Fill (PDF) Float Shoes and Collars .................................................................... 10-7
Unit A Quiz .......................................................................................................................................... 10-8
Unit B: Casing Attachments ....................................................................................................................10-9
Clamps..................................................................................................................................................10-9
Centralizers...........................................................................................................................................10-9
Wall Cleaners ..................................................................................................................................... 10-10Cement Baskets ..................................................................................................................................10-11
Unit B Quiz ........................................................................................................................................ 10-12
Unit C: Primary Cementing Plugs ......................................................................................................... 10-13
Bottom Plugs......................................................................................................................................10-13
Top Plugs............................................................................................................................................10-13Latch-down Plugs...............................................................................................................................10-14
Unit C Quiz ........................................................................................................................................ 10-16
Unit D: Multiple Stage Cementing Tools ..............................................................................................10-17
Type-P External Sleeve (ES) Cementer .............................................................................................10-17
Type-H External Sleeve (ES) Cementer.............................................................................................10-18Stage Tool Plug Sets .......................................................................................................................... 10-18
Full-Opening (FO) Multiple-Stage Cementer .................................................................................... 10-19
External Sleeve Inflatable Packer Collar (ESIPC) .............................................................................10-20
Unit D Quiz ........................................................................................................................................ 10-21
Answers to Unit Quizzes....................................................................................................................10-22
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Introduction
Use for Section Notes
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Unit A: Guiding and Floating Equipment
Introduction
During the early stages of the drilling process,
the hole will be lined with steel casing to prepare
the well for production or deeper drilling. The
steel casing provides a smooth bore for the tools
necessary to drill and complete the well. The
types of downhole equipment discussed in this
section contribute to a good cement job; they
help ensure a uniform cement sheath behind the
casing.
As you learn more about downhole equipment,
keep in mind that any item that will be used
inside the casing must be made of drillable
material.
Topics
This chapter covers the following topics:
A. Guiding and Floating Equipment
B. Casing Attachments
C. Primary Cementing Plugs
D. Multiple-Stage Cementing Tools
Learning Objectives
Upon completion of this section, you should be
familiar with:
Functions of downhole equipment
Descriptions of the basic types of equipmentused downhole
Uses and applications of downholeequipment
Unit A: Guiding and Floating Equipment
Guiding equipment helps guide casing past
ledges and doglegs to the bottom of the hole.Floating equipment allows casing to be run in
the hole partially empty, which takes some of
the stress off of the rig structure and draw-
works. Also, backpressure valves in floatingequipment permits the release of pressure in the
casing, after the cement job, to reduce
microannulus problems. A microannulus may be
created when stressed casing (due to internal
pressure) is allowed to relax after cement has
already hardened and bonded. As the casing
contracts, the slight reduction in casing outside
diameter results in a very narrow gap betweenthe cement and casing that may allow fluid
travel and compromise the isolation of zones.
Some of the more commonly used types of
guiding and floating equipment will be dis-
cussed in this unit. These include:
Shoes
Collars
Backpressure valves
Guide Shoes
Guide shoes and down-jet guide shoes have the
following primary purposes:
They protect the casing string from theimpact associated with landing casing on
bottom
They direct casing away from ledges,reducing the chance of sidewall cave-in
They help casing pass through narrow,deviated holes and areas with hard shoulders
The standard guide shoe has a large-ID hole
through its center, allowing maximum cement
pumping rates and the passage of self-fill orifice
tubes and balls dropped in the casing string. The
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Unit A: Guiding and Floating Equipment
rounded nose of these guide shoes is made from
high-strength cement that can be drilled out
easily with tri-cone rock bits or PDC bits.
Down-jet guide shoes have additional side ports
in the steel case that allow fluids to discharge
through both the cement nose and the ports. Thejetting action of the fluid pumped through these
ports helps remove wellbore cuttings and filter
cake.
Figure 10.2 - Super Seal Float Shoe
Super Seal II High-Port Up-Jet(HPUJ) Float Shoe
The High-Port Up-Jet (HPUJ) float shoe jets the
formation face to remove detrimental mud cake
and cuttings, increasing the chances of a
successful cement-to-formation bond. The high
circulation rates and cement flow rates that are
possible with the Super Seal II float valveallow turbulent flow at the shoe without
damaging the float valve.
Figure 10.1 - Guide Shoe
Super Seal II Float Shoe
The Super Seal II standard float shoe attaches
to the lower end of the casing string. This floatshoe includes the Super Seal II backpressure
valve assembly, which helps prevent cement in
the cased hole from re-entering the casing ID.
The plastic valve and stem materials are
surrounded by drillable concrete, making the
equipment easy to drill out with PDC or tri-cone
rock bits. The high-strength, durable rounded
nose safely guides the casing to the bottom of
the hole. This equipment is available in all
tubing and casing sizes with API 8-rd and
buttress threads. The standard casing grade is K-
55 material. Customers can request any casing
grade and premium thread by special order.
The HPUJ shoe includes six fluid-discharge
ports strategically placed to jet the circulation
fluid or cement upward, enhancing fluid
turbulence far above the floating equipment.
These up-jet ports, along with four (or fewer)
down-jet ports, distribute the fluid in the annular
space above and below the float shoe, helping
prevent channeling near the shoe.
Approximately 40% of the fluid pumped
through the equipment is discharged at a high
velocity through the bottom of the float shoe,
removing material in its path and helping
maneuver the casing past ledges and tight
sections of the wellbore.
If the casing string is reciprocated during
cementing, cement jetted through the exit ports
remove mud cake from the formation face. Field
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Unit A: Guiding and Floating Equipment
reports indicate that the HPUJ float shoe can
substantially reduce the number of casing strings
requiring secondary squeeze cementing
operations. All casing sizes of the Super Seal
II HPUJ float shoe use the same autofill strap
used for the Super Seal II float valve. When
engaged, this strap allows the casing to fillautomatically with wellbore fluid while it is
being run in the hole, saving time and reducingthe ram effect of running casing.
Figure 10.4 Super Seal II Down-JetFloat Shoe
Super Seal II Float Collar
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
during cementing operations. The float collar is
normally installed one or two joints above the
float or guide shoe. All casing-size Super Seal
II float collars include an autofill strap (at no
additional cost). This strap, which is installed
between the valve and pressure seat, is
deactivated by flow rate. The autofill strapallows wellbore fluids to enter the casing with
the first joint, reducing surge pressure on the
formation and reducing casing fill time from the
surface. When the autofill strap is pumped loose
with a high fluid rate, the float valve is re-turned
to a dependable Super Seal II backpressure
valve for floating or cementing. The autofill
strap will deactivate if the flow through the
valve reaches a predetermined rate (4 bbl/min
for the 2 in. valve and 6 bbl/min for the 4
in. valve).
Figure 10.3 Super Seal II High-Port Up-Jet (HPUJ) Float Shoe
Super Seal II Down-Jet FloatShoe
The Super Seal II down-jet float shoe includes
the Super Seal II float valve, which prevents
cement backflow from re-entering the casing ID.
In addition to the center hole through the float
valve, four to six fluid ports are drilled in the
outer case below the float valve. These ports
direct some of the fluid downward during
circulation. Pressurized fluid jets out of the side
ports and the guide nose, helping removecuttings and filter cake, creating turbulence
around the shoe, and improve cement
distribution and casing-to-formation bonding.
Additionally, the external jets on the outer case
provide an alternative cement flowpath if the
bottom center port becomes plugged with well
debris.
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Unit A: Guiding and Floating Equipment
Figure 10.5 Super Seal Float Collar
Insert Flapper Float Valve
The insert flapper float valve is a backpressure
check-valve assembly installed between the pin
and box ends of API 8-rd or buttress thread
casing joints. The insert flapper float valve is
used for casing flotation and cementing
operations in wells with moderate temperature
and depth. It can be used for differentialpressures up to the collapse pressure of the
lightest weight of J-55 casing in the casing size
in which it is run. The insert flapper float valve
can be installed in long or short API 8-rd or
buttress casing coupling. Because of limited
space between the casing box and pin, insert
flapper float valves are not available for
premium-thread casing. One or more insert
valves can be run in a casing string or in
conjunction with a standard float shoe or guideshoe.
Because they are made from aluminum, insertflapper valve assemblies can be drilled out easily
with a medium-tooth, tri-cone rock bit. PDC bits
should not be used to drill out insert flapper
valves.
The insert float valve has a large flow area and
can be easily converted to autofill equipment if
an orifice self-fill unit is installed. The self-fill
unit includes a weighted plastic valve and plastic
orifice tube. The orifice tube holds the flapper
open until a weighted plastic setting ball is
dropped into the casing. Once the ball reaches
the valve seat, pressure is applied to shear out
the plastic orifice tube, which allows the valve to
close. This equipment operates efficiently inmud systems containing high concentrations of
lost-circulation material.
The insert float valve is more economical than
standard floating equipment but should not be
used under any of the following circumstances:
in wells over 7000 ft
where pressures exceed the collapsepressure of the lightest weight range of
casing being used (for example, 17 in., 20
lb/ft J55) when bottomhole temperature is more than
200F .
Figure 10.6 Insert Flapper Float ValveSelf-Fill Unit and Insert Flapper Float Valve
Backpressure Valves
Backpressure valves were briefly discussed
under float collars. They are one way valves that
keep the flow of fluid from re-entering the
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Unit A: Guiding and Floating Equipment
Automatic fill equipment is used tocasing. Two common types of valves are the
flapper and poppet valves (Fig. 10.6). reduce rig time
The flapper valve uses a spring-loaded flapper
that has a rubber coating around a beveled edge,
which seals on a tapered seat. The spring is a
low force type (it requires only a small amountof pressure to open the valve).
reduce fluid surge effects of running casing
prevent the sticking of casing
Flapper type equipment can be converted toautomatic fill by installing a fill tube through the
middle of the tool. This holds the flapper off its
seat.
When pumping stops, the spring pushes the
valve back against the seat, preventing fluid
from entering the casing.The diameter of the fill tube can be chosen to
somewhat control the flow rate of fluid into the
casing. To stop the flow rate and convert from
automatic fill to float valve, a ball must be
landed on a seat in the fill tube, pressure applied,
and sheared out of the valve.
The poppet valve uses a rubber-coated, spring-
loaded valve, which seals on a plastic seat. The
poppet is pushed downward by fluid pressure
allowing the fluids to be pumped through the
valve. Once the pumping has stopped, a shut off
is created when the poppet is pushed up against
the seat by a spring.To convert the poppet valve to automatic fill,
specially designed stand-off lugs are insertedbetween the spring loaded valve and the seat.
This allows fluid flow to occur through the valve
from either direction. To cause the valve to act
as a backpressure valve, a specified pump rate
must be achieved that will open the valve
sufficiently to free the stand-off lugs. The lugs
then flow downward from the poppet, allowing
the valve to seat when pumping is stopped.
Flapper ValveFlapper Valve Poppet ValvePoppet Valve
Pressure Differential Fill (PDF)
Float Shoes and Collars
The pressure differential fill (PDF) float shoe
and collar include a float valve. This valve
allows casing to be filled while it is run in the
hole, and it allows fluid circulation at any time
without deactivating the fill unit. PDF float
shoes and collars can be run in the same casing
string. They allow fluid to enter the bottom of
the casing while maintaining a constant
differential pressure between the inside and
outside of the casing at the floats. This pressure
maintains a constant fluid height inside the
casing.
Figure 10.7 Back Pressure Valves
To decrease differential pressure in deep holes
and minimize the possibility of collapsing the
casing, it is necessary to allow some fluid to
enter the casing as it is lowered in the hole.Flapper and poppet valve systems can be
modified to allow the casing to be filled
automatically, but you will have no control over
how much fluid will enter; the amount of fluid in
the annulus directly affects the amount of fluid
which enters the casing.
PDF floating equipment is supplied in the
differential-fill mode, and it is ready to be run in
the hole. After all casing has been run, a
weighted plastic ball is dropped in the casing
from the surface and pumped through the tool.
This procedure deactivates the differential-fill
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Unit B: Casing Attachments
option. After the ball passes the float collar
and/or shoe, the PDF flapper closes against its
seat, preventing cement from re-entering the
casing ID.
The PDF floating equipment is supplied in either
a float collar or a float shoe in common casingsizes. All equipment run with these tools must
have an ID large enough to allow passage of the
weighted ball that releases the backpressure
valve. Tool sizes from 4 1/2to 6 5/8in. require a
1 3/8in. diameter ball, while tools 7 in. and
larger require a 2 3/8in. diameter ball.
PDF floating equipment should not be used in
wells deviated more than 30 from vertical, and
it should not be drilled out with PDC bits. PDF
equipment cannot be used with Super Seal II
floating equipment.
Figure 10.8 Pressure Differential Fill(PDF) Float Shoe and Collar.
Unit A Quiz
Fill in the blanks with one or more words to check your progress.
1. The purpose of guiding equipment is to help casing travel downhole without causing
____________________________________________.
2. The purpose of floating equipment is to help prevent ____________________ problems.
3. A (an)______________________ is run on the first joint of casing.
4. Side ports in a guide shoe help to remove __________________________ and
____________________ .
5. The main difference between a guide shoe and a float shoe is that a float shoe contains a
_____________________. Fluid can only flow ______________ the casing.
6. A (an)___________________________________ can sometimes be used instead
of standard float equipment in a well less than 7000 ft and at bottomhole
temperatures less than 200F.
7. The figure to the right is a (an) ___________________ type valve.
8. Some fluid should enter the casing in deep holes to decrease the differential
pressure to minimize the possibility of _______________________.
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Unit B: Casing Attachments
Unit B: Casing Attachments
CentralizersCasing attachments are devices installed on theoutside of the casing string to help successfully
complete a primary cementing job.
Bow-Spring CentralizersIncluded in this unit are
Clamps Bow-spring centralizers help center the casing inthe wellbore during cementing operations,
allowing the cement to be evenly distributed
around the casing string. The degree to which
the casing is centered (standoff) depends on the
performance of the centralizer and the spacing
between the centralizers installed on the casing
OD. Bow-spring centralizers, both welded andnonwelded, provide the following advantages:
Centralizers
Wall Cleaners
Cement Baskets
Clamps
All casing attachments must be installed or
fastened to the casing by some method. 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 of different types of clamps (Fig. 10.9).
One type is simply a friction clamp that uses a
set screw to keep the clamp from sliding.
They help center the casing in the wellbore,allowing even distribution of cement around
the casing.
They help reduce casing drag on thewellbore during casing running operations.
They help prevent differential sticking of thecasing.
Another type uses spiral pins that are driven
between the clamp and the casing to supply the
holding force. Others have dogs (or teeth) on the
inside, which actually bite into the casing.
Where corrosion problems exist, any clamp that
could scar the surface of the casing is unusable.
Clamps should drawnot pushthe casing
equipment into the hole.
They increase fluid turbulence at the tool,
helping remove filter cake from thewellbore.
They can be run through hole restrictions inthe wellbore or through smaller casing
strings that are cemented in the well, thereby
centering the casing below the restriction.
Welded Bow-Spring Centralizer
Welded bow-spring centralizers are available in
two styles: slip-on and hinged. Slip-on
centralizers are manufactured with solid endrings, requiring the centralizer to be slipped on
the casing OD during installation. Hinged
centralizers are manufactured in segments,
allowing the centralizer to be installed easily
around the casing OD. Hinge pins hold the
segments together during installation. All
welded bow-spring centralizers are
manufactured to API Specification 10D.Figure 10.9 - Clamps
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Unit B: Casing Attachments
Centralizers with turbofins attached to each bow
spring are designed to create localized turbulent
fluid flow at the centralizer. The turbofins divert
the fluid flow, more evenly distributing cement
around the casing.
The dual-contact (double bow) welded
centralizer is designed for small-clearance
casing-to-hole size applications. The centralizer
will perform as a standard bow centralizer in
holes up to 1/2in. smaller than the centralizers
nominal OD. When run in holes less than 1/2 in.
smaller than the OD, the center of the centralizercontacts the casing OD, performing as a rigid
centralizer. Because of its high restoring forcewith very little spring deflection, the dual-
contact centralizer is excellent for deviated and
horizontal wellbores. The dual-contact
centralizer should only be installed between a
collar and stop ring never over a casing collar.
All welded and nonwelded bow-springcentralizers are available in most common
hole/casing sizes.
Figure 10.11 Nonwelded Bow-SpringCentralizer
Figure 10.10 Welded Bow-SpringCentralizer Wall Cleaners
Since drilling fluid and cement should not be
mixed together, good cement bonds between
casing and cement and between cement and
formation depend upon removal of the filter
cake from across formations.
Nonwelded Bow-Spring Centralizer
Nonwelded bow-spring centralizers are available
in the hinged style only. The bow springs of this
centralizer are attached to the end rings without
welding. The centralizer bow end is connected
to the end rings with a locking tab that bears the
load force on the centralizer. The centralizers aresupplied in hinged segments joined by hinge
pins in each segment. All nonwelded centralizers
meet or exceed the requirements of API
specification 10D, which dictates the minimum
restoring and maximum starting forces for
centralizers for various casing/hole size
combinations.
Wall cleaners or scratchers (sometimes called
mud stirrers) are installed on the outside of thecasing to mechanically remove mud filter cake
from the wall of the hole with spring steel spikes
or cables.
Mechanical cleaners on the casing agitate the
mud and make it easier to displace. The motion
of the scratchers breaks the gel strength of the
mud in the annulus and helps thin the fluid so
that it can be displaced out of the hole. Mud
removal is also helped by pumping the cement
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Unit B: Casing Attachments
slurry at a rate high enough to create turbulent
flow.
Two common types of scratchers are rotation
and reciprocation. The rotation-type scratcher
(Fig. 10.12) cleans the formation when the
casing is rotated at about 15 to 20 rev/min. Acontinuous length of scratchers is needed across
the zones to be cleaned.
Cable-TypeCable-Type Wire-TypeWire-Type
Wire TypeWire Type
Cable TypeCable Type
Figure 10.12 - Scratchers
The reciprocation-type scratcher has either long
steel spikes (Fig. 10.12) or a cable (Fig. 10.12).
These devices scratch or clean the formation as
the casing is picked up 10 to 15 ft off the bottom
of the hole. Be carefulsome reciprocation typescratchers can be installed upside down and
would be useless when they reach the producing
formation.
It is good practice not to have scratchers
working across a lost circulation zone, since the
filter cake and lost circulation material should
not be removed. However, it is possible to run
the reciprocation type (no cable type) scratcher
in a lost circulation zone with minimal
disturbance of the filter cake.
Movement of the casing, in addition to the use
of mechanical cleaners, greatly increases the
ability of the cement slurry to more completely
displace the mud and prevent mud channels
through the cement. This movement can be
either rotation or reciprocation during the
circulating and displacing operations.
Cement Baskets
Cement baskets are also installed on the outsideof casing. They help support some of the
hydrostatic pressure that the cement slurryproduces until it sets and protect the producing
formation against cement contamination. A
cement basket has a canvas or metal liner
supported by steel staves (Fig. 10.13).
This canvas liner filters out the cement solids,
which may form a bridge between thecasingand hole. The maximum amount of pressure that
any cement basket should ever be expected to
hold is approximately 50 psi. A cement basketshould be able to travel the full length of the
pipe joint.
Figure 10.13 Cement Basket
Cement baskets are used
above weak zones that may break downunder the hydrostatic pressure of the cement
slurry for cementing casing through a shoe joint to
provide extra support for the column of
cement.
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Unit C: Primary Cementing Plugs
Unit B Quiz
Fill in the blanks with one or more words to check your progress.
1. If a casing attachment is not installed over a casing collar, then a (an) _____________ is used to
fasten the equipment to the casing.
2. If youre working on a well that will likely have corrosion problems, youll want to avoid the use of
any clamp that could ____________ the casing, like a clamp which has ________________.
3. A uniform cement sheath around the casing largely determines the effectiveness of the
__________________ between the wellbore and casing.
4. The casing attachments used to center the casing in the hole are called
_______________________________________.
5. Scratchers are used to mechanically remove ________________ from formations.
6. Rotation type scratchers clean the formation when the casing is___________.
7. Reciprocation type scratchers clean the formation when the casing is
______________________________.
8. In addition to using mechanical scratchers, mud displacement is also helped by the
___________________ of cement, and the _______________________ of the casing during a
cement job.
9. Cement baskets support some of the _________________________, which the slurry produces until
it sets. They have a ____________________ liner, which filters out cement solids that can form a
___________________between the casing and the wellbore.
10.Cement baskets are usually used above a ________________________.
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Unit C: Primary Cementing Plugs
Unit C: Primary Cementing Plugs
Plugs used in primary cementing minimize
cement contamination in the casing by wiping
the casing clean and serving as a barrier between
wellbore fluid and cement. Included in this unit
areCasing
Top Cementing Plug
CementSlurry
Boundary
Layer of Mud
Mud
Accumulation of
mud-contaminatedcement from wipedaway boundarylayer
Bottom plugs
Top plugs
Latchdown plugs
Bottom Plugs
The function of the bottom plug is to enter the
casing ahead of the cement slurry. It wipes mud
and solids from the casing wall and keeps those
solids ahead of the plug. Bottom plugs are
almost always used in primary cementing,except when lost circulation materials are being
run with the cement.
Figure 10.15 Top plug run without abottom plug.
Top Plugs
Bottom Plugs
When the bottom plug reaches the float collar or
float shoe, the differential pressure between the
inside of the casing and annulus ruptures the
diaphragm on top of the plug to allow the slurry
to flow out of the shoe and up the annulus. The
plug body is strong enough to withstand the
forces of impact and the differential pressure to
rupture.
Top Plugs
A top plug is pumped down by displacement
fluid after all the slurry has been pumped (Fig.
10.15). It prevents the displacement fluid from
channeling through the more viscous cement
slurry. Top plugs have no diaphragm and fluid
can not be pumped through them. When it
reaches the top of the bottom plug, pressure will
build up and indicate that the job is complete. Figure 10.16 Cross-section of cementingplugs.
Although the top and bottom plugs perform
somewhat the same function (separating two
fluids), they are quite different structurally (Fig.
10.16).
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Unit C: Primary Cementing Plugs
Top plugs have rubber wipers to wipe the casing
and can withstand considerably more pressure.
To help with easy identification, top plugs are
black and bottom plugs are red. Top and bottom
plugs have a solid core of plastic.
Latch-down Plugs
Latch-down plugs are usually used with tubing,
casing and interstring cementing; however, they
may also be used with conventional casing float
equipment. The latch-down plug functions as a
top plug, and its snap ring locks into a groove inthe baffle when it is pumped down after the job
(Fig. 10.17). The latch-down feature helps
ensure that the cement and top plug will not
move back up the casing.
The Latch-down Casing Plug and Baffle may be
used above most conventional floating
equipment to help control fluid and pressure
from below. The Latch-down plug may also be
used when there is no floating equipment run on
the casing string. Prevention of fluid entry into
the casing string also permits immediate release
of surface pressure when the cement column has
been pumped in place. Additionally, the latch-
down feature helps assure that the cement or top
plug will not back up the casing which might
necessitate drilling out if completions are madeclose to the float collar.
The baffle is installed either on top of the float
or in the desired casing collar above and held in
place by the pin end of the casing. A rubber
gasket seals against the upper joint and the
coupling threads. The latch-down plug acts as
the top cement plug and follows the cement
slurry down the casing to reduce the possibility
of contamination or channeling with the drilling
mud or fluid used to displace the cement. When
the plug reaches the baffle, normally 500 to
1,000 psi above circulating pressure forces thelatching nose of the plug into the baffle and
locks it in place.
The maximum pressure that the baffle will
withstand is dependent upon the proper make-up
of the casing joints and the weight range of the
casing. A differential of 3,000 psi should not be
exceeded in any light weight casing. Higher
differential pressures are allowable in heavier
weight casing with a maximum of 5,000 psi inthe heaviest weights.
Figure 10.17 Latchdown plug and baffle.
The latch-down baffle may be installed either on
top of the float shoe or float collar, or in any
casing collar above a float collar. It is held in
place by the thread end of the casing. A rubber
seal on the plug provides a fluid seal from both
directions.
Instead of a float collar, a latch-down plug may
be used in conjunction with a guide shoe to save
rig time.
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Unit C: Primary Cementing Plugs
Summary of Downhole EquipmentType of Equipment Major Function(s) Location
Guide Shoe To guide casing into wellTo help protect casing ends
First joint of casing
Float Shoe Same as guide shoeTo prevent fluid or cementflowback
First joint of casing
Baffle Collar To provide a landing seat forplugs
1-3 joints above shoe (dependingon depth of well)
Float Collar Same as baffle collarTo prevent fluid or cementflowback
1-3 joints above shoe
Insert Float Valve Same as float collar In casing collar
Back Pressure Valve To prevent fluid or cementflowback
In floating equipment
Automatic Fill Valve To automatically allow fluid intothe casing to eliminate rigdowntime cause by stopping tofill the casingTo reduce ram effect
In float shoes and collars
Differential Fill Valve To allow fluid to enter casing todecrease differential hydrostaticpressure
In float shoes and collars
Clamp To fasten attachments As required
Centralizer To center casing in hole 1 per joint from 200 ft. aboveformation to 200 ft below it, 1 per
3 joints in open holeWall Cleaner To remove mud filter cake from
wall of holeFrom 100 ft above producingformation through it
Cement Basket To help protect formations fromhydrostatic pressure of cementuntil it sets
Above weak formations
Bottom Plug To Act as a mechanical spacerbetween mud and cement slurry
Between well fluids and cement
Top Plug To act as a mechanical spacerbetween cement slurry anddisplacement fluid
Between well fluids and cement
Latch-down Plug Same as top plug Between well fluids and cement
Multiple Stage Cementing Tools To cement in two (or more)stages
Depends on hole conditions
Formation Packer Equipment To pack off formationsTo isolate zones
Depends on hole conditions
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Unit D: Multiple Stage Cementing Tools
Unit C Quiz
Fill in the blanks with one or more words to check your progress.
1. Primary cementing plugs minimize _____________________ by _____________ the casing clean.
2. These plugs serve as a (an) _____________ between fluids and cement.
3. A bottom plug enters the casing _______________ the cement slurry. The _________________
pressure between the inside of the casing and the annulus causes the plug(s) ________________ to
rupture.
4. Bottom plugs are almost always used in primary cementing, except when
______________________________________ is (are) being run.
5. A top plug enters the casing ______________________ the cement slurry. When it seats on/at the_______________________, pressure will increase. This indicates that cement placement is
____________________.
6. _____________________ are black and have a deep cup on top; ______________________are red
and shallow.
7. A (an)_______________________ plug functions in the same way as a top plug, but it has a
(an)______________________, which locks into a groove in its baffle.
8. To save rig time, you might use a latchdown plug in conjunction with a guide shoe instead of a (an)_______________________.
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Unit D: Multiple Stage Cementing Tools
Unit D: Multiple Stage Cementing Tools
During multiple-stage cementing, cement slurry
is placed at predetermined points around the
casing string in several cementing stages.
Multiple-stage cementing can be used for the
following applications:
heavy-duty seals and backup rings that
prevent seal damage during operations
compatibility with three-stage cementingapplications
cementing wells with low formation
pressures that will not withstand the
hydrostatic pressure of a full column ofcement
Type-P External Sleeve (ES)Cementer
Type-P external sleeve (ES) cementers can be
used in most vertical wells, regardless of depth,
pressure, or temperature. The Type-P cementer
should not be used in wells deviated more than30 from vertical when using a free-fall opening
plug. Otherwise, the free-fall opening plug will
not fall by its own weight through well casing.
Type-P ES cementers are available in 4 1/2to 20
in. casing sizes. The standard case material
grade is L-80 steel. Other casing grades can be
provided at the customers request.
cementing to isolate only certain sections
of the wellbore
placing different blends of cement in thewellbore
cementing deep, hot holes where limitedcement pump times restrict full-bore
cementing of the casing string in a single
stage
Halliburton manufactures two types of external
sleeve (ES) stage cementers: the Type-P ES
cementer, which is a plug-operated stage
cementer, and the Type-H ES cementer, which is
a hydraulically opened stage cementer. Both the
Type-P and the Type-H cementers have thefollowing features:
short, single-piece mandrel design without
threaded or welded segments
field-adjustable opening and closing
pressures
clear surface indications of opening and
closing
smooth bore after drillout with no exposed
sleeves to interfere with the operation of
workover tools on subsequent trips in and
out of the casing strings
drillability with either PDC or roller-cone
rock bits
compatibility with second-stage bottom
plug sets Figure 10.18 - Halliburton Type-P ExternalSleeve (ES) Cementer
external closing sleeve that is locked
closed by the top cementing plug
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Unit D: Multiple Stage Cementing Tools
During cementing operations, the first-stage
cement is mixed and pumped into the casing in a
conventional manner. The first-stage shutoff
plug, which is launched in the casing after the
first-stage cement, lands on the shutoff baffle
installed on the float collar. This shutoff plug
provides a positive shutoff, which helps preventcement over displacement around the shoe joint.
After the first-stage cementing operation iscompleted, a free-fall opening plug is dropped
down the casing ID to land and seal in the
cementer. Pressure applied to the casing opens
the cementer, allowing wellbore fluid to be
pumped into the casing/wellbore annulus. Fluidcirculation to the surface is normally maintained
until the first-stage cement has set up in the
annulus. The second-stage cement is then
pumped through the open cementer ports,
followed by a second-stage closing plug. Theclosing plug seats in the cementer, and pressure
is applied to the casing to close the tool. After
both stages are cemented, the cementer seats,
and plugs are drilled out with a rock bit or a
PDC bit.
Figure 10.19 Halliburton Type-H ExternalSleeve (ES) Cementer
plug dropped through the casing ID. The Type-
H cementer can be used in highly deviated wells,
in horizontal wells, and above an openhole
completion or slotted liner. After the second-
stage cementing operation, a second-stage
closing plug pumped behind the second-stage
cement closes the cementer. Lock rings in the
external closing sleeve lock the cementer in the
closed position. After both cementing stages, the
cementer seats, and plugs are drilled out with a
roller-cone rock bit or a PDC bit.
Type-H External Sleeve (ES)Cementer
The Type-H external sleeve (ES) cementer is a
hydraulically opened stage cementer that can be
used in most wells, regardless of depth, pressure,
or temperature. Although the Type-H ES
cementer operates much like a Type-P cementer,
it can be opened with internal casing pressure in
addition to the free-fall plug after the first-stage
shutoff plug lands. This design feature saves
time by eliminating the need for dropping a free-
fall plug from the surface. A baffle adapter is
recommended in the casing string above the
float collar to seat the first-stage shutoff plug.
Type-H ES cementers are available in 4 1/2to 20
in. casing sizes. The standard material grade is
L-80 grade steel. Other grades can be provided
at the customers request.
Stage Tool Plug SetsWhen the first-stage cementing plug has seated,casing pressure can be applied to hydraulicallyopen the Type-H ES cementer. Normally, thecementer should be opened immediately after
the first-stage cement is pumped and the shutoff
plug has been bumped. If the well is deviated
less than 30 from vertical, the Type-H ES
cementer can also be opened with a free-fall
Plug sets for operating both Type-P and Type-H
cementers must be ordered separately from the
cementer. The individual components of each
plug set depend on the type of tool to be
operated.
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Unit D: Multiple Stage Cementing Tools
A standard plug set for two-stage cementing
consists of the following equipment:Full-Opening (FO) Multiple-Stage Cementer
a shutoff baffle installed on top of the float
collar (for 8-rd and buttress) The full-opening (FO) multiple-stage cementeris used to place an indefinite number of cement
stages or other fluids at selected points along theoutside of a casing string. An indefinite number
of FO cementers can be run in the casing string.
Standard material grade is L-80. Other grades
can be supplied at customers request.
a shutoff plug (for both Type-P and Type-
H cementers)
a free-fall opening plug (required for the
Type-P cementer; optional for the Type-H
cementer)
a closing plug (for both Type-P and Type-
H cementers)When one or more FO cementers are run in the
casing string, the first stage of cement can be
pumped in the conventional manner. All
subsequent cementing stages are pumped
through a workstring run inside the casing.
Shifting tools run 8 to 10 ft apart on the
workstring are used to open or close the FO
cementer.
a baffle adapter installed one or more
joints above the float collar (for the Type-
H cementer)
Unlike plug-operated or hydraulically opened
stage cementers, FO cementers provide the
following benefits:
They do not require operating plugs,
eliminating the need for drilling out after
cementing.Figure 10.20 Halliburton Type-P StageTool Plug Set FO cementers can be used to test, treat,
and evaluate a zone in the well before it is
closed.
Multiple FO cementers can be run in thesame casing string.
Operators can open and close these tools
as many times as necessary.
A packoff between the workstring and casing is
required to direct fluid out the open ports of the
FO cementer.
Figure 10.21 Halliburton Type-H StagePlug Set
FO cementers are available by special order for
any casing grade or premium thread. For pricing
information, customers must provide
information about casing OD, thread type,
weight, grade, and hole size.Use of a baffle adapter is the preferred method
when using a Type-H cementer with a first-stage
bottom plug.
Wells can also be cemented in three stages with
two cementers and a three-stage plug set. A
three-stage plug set must be ordered separately
from the cementers.
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Unit D: Multiple Stage Cementing Tools
Figure 10.22 Halliburton Full-Opening(FO) Multiple-Stage Cementer
External Sleeve InflatablePacker Collar (ESIPC)
The external sleeve inflatable packer collar
(ESIPC) is a combination of the ES (Type H or
Type P) cementer and a casing inflation packer.This tool provides controlled packer element
inflation through the stage-tool opening seat,
eliminating hydraulic valving bodies normally
used with inflatable packer elements. The rubber
inflatable packer element is constructed with
reinforcing metal slats to reduce packer element
damage during inflation. This inflatable packer
element allows packer differential pressures up
to 4,000 psi.
The ESIPC is commonly used in horizontal well
applications for cementing casing in the bend
radius or vertical portion of the wellbore abovean openhole completion or a slotted liner. The
packer element is inflated to prevent cement
from flowing downhole when it is pumped into
the annulus above the tool. The Type-H ESIPC
is available by special order for any casing grade
or premium thread. For pricing information,
customers must provide information about
casing OD, thread type, weight, grade, and hole
size.
Figure 10.23 Halliburton External SleeveInflatable Pack Collar (ESIPC) Type H
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Unit D: Multiple Stage Cementing Tools
Unit D Quiz
Fill in the blanks with one or more words to check your progress.
1. Multiple stage cementing tools are used when you want to cement behind the same casing string in
___________ stages.
2. The decision to cement in multiple stages would be made when high hydrostatic pressure might cause
the _________________ to break down.
3. If the Type-H ES cementer doesnt open with _________________ pressure, a
_____________________ can be dropped if the well is not deviated more than _______.
4. During the second stage, cement is displaced through _______________ in the multiple stage tool.
5. A multiple stage tool called a __________________________ has two sleeves which are operated_____________________. One sleeve moves to uncover the __________ and the other moves to
close the _____________________.
6. The first part of the plug set to enter the hole when the free fall method is used is the
_______________________.
7. Once the opening plug has landed, the Type-P ES cementer is opened by ___________________.
8. Unlike the ES cementers, the FO cementer operates _____________________ and can be opened and
closed _________________________________.
9. Formation packer equipment is used when you want to ________________ cement from flowing
_____________________.
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Unit D: Multiple Stage Cementing Tools
Answers to Unit Quizzes
Items from Unit A Quiz Refer toPage
1. damage to hole or casing 10-3
2. overweight 10-3
3. float shoe 10-4
4. wellbore cuttings, filter cake 10-4
5. backpressure valve, into 10-4
6. insert flapper float valve 10-6
7. flapper 10-7
8. collapse 10-7
Items from Unit B Quiz Refer toPage
1. clamp 10-10
2. scar, dogs (teeth) 10-10
3. cement 10-10
4. centralizers 10-10
5. filter cake 10-12
6. rotated 10-12
7. picked up 10-12
8. pumping rate, movement 10-11,12
9. hydrostatic pressure, canvas,bridge
10-12
10. weak zone 10-12
Items from Unit C Quiz Refer toPage
1. contamination, wiping 10-14
2. barrier 10-14
3. ahead, differential, diaphram 10-14
4. lost circulation materials 10-14
5. after, bottom plug, complete 10-14
6. Top plugs, bottom plugs 10-15
7. latch-down, snap ring 10-15
8. float collar 10-15
Items from Unit D Quiz Refer toPage
1. several 10-17
2. formation 10-17
3. hydraulic, free fall plug, 30 10-17,18
4. ports 10-18
5. Type-H ES Cementer,hydraulically, ports, ports
10-18
6. shut off baffle 10-197. pressure 10-18
8. mechanically, as many times asnecessary
10-19
9. prevent, downward 10-20