Halliburton Cementing
Casing Equipment
and Accessories
Sales of Halliburton products and services will be in accord solely with the terms and conditions
contained in the contract between Halliburton and the customer that is applicable to the sale.
www.halliburton.com
®
2001 Halliburton Energy Services
Printed in U.S.A.
Halliburton Cementing
Casing Equipment
and Accessories
Halliburton Energy Services, Inc.
Floating and Guiding Equipment ............................ 1
Super Seal™ II Floating Equipment ............................................. 1
Super Seal™ II Down-Jet Float Shoe .................................... 1
Super Seal™ II Nonrotating (NR) Float Collar ....................... 1
Super Seal™ II High-Port Up-Jet Float Shoe ........................ 2
Double-Valve Super Seal™ II Floating Equipment ................ 2
Super Seal™ II Tubing-Size Floating Equipment .................. 3
Super Seal™ II Float Shoe .................................................... 3
Super Seal™ II Float Collar ................................................... 3
Pressure Differential Fill (PDF) Float Shoes and Collars ............. 4
Insert Float Valve ......................................................................... 4
Guide Shoes ................................................................................ 5
Load-Carrying Float Equipment ................................................... 5
Inner-String Cementing Equipment ........................ 6
Cementing Plugs ...................................................... 8
Standard Five-Wiper Cementing Plugs ................................. 8
Nonrotating (NR) Cementing Plugs ....................................... 8
Subsurface Release (SSR)® Cementing Plug System .......... 9
Multiple-Stage Cementing Tools ........................... 10
Type-P External Sleeve (ES) Cementer .............................. 10
Type-H External Sleeve (ES) Cementer ............................... 11
Stage Tool Plug Sets ............................................................ 11
Full-Opening (FO) Multiple-Stage Cementer ....................... 12
External Sleeve Inflatable Packer Collar (ESIPC) ............... 13
Type-H Selective-Release (SR) Plug Set ............................ 14
Formation Packer Shoes/Collars .......................... 15
852-Series Formation Packer Shoe/Collar .......................... 15
855-Series Formation Packer Shoe/Collar .......................... 16
Super-Fill™ Equipment .......................................... 17
Super-Fill™ Collar ............................................................... 17
Super-Fill™ Diverter Tool .................................................... 18
Bow-Spring Centralizers ........................................ 19
Welded Bow-Spring Centralizer .......................................... 19
Nonwelded Bow-Spring Centralizer ..................................... 19
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Halliburton Energy Services, Inc.
Floating and Guiding Equipment
Super Seal™ II Floating Equipment
Super Seal™ II floating equipment is installed in the casing string and becomes an integral
part of the casing string. This equipment helps float and cement the casing in the well. The
equipment’s basic backpressure and temperature ratings (5,000 psi and 400°F) allow it to be
used in most wells. The plastic valve materials and surrounding shear- and shockloadresistant concrete exceed the strength requirements for landing cementing plugs. The valve
assembly and the cement holding the valve assembly in place can be drilled out easily with
roller-cone rock bits or polycrystalline diamond compact (PDC) bits after cementing operations. No steel or cast-iron materials are used in the drillable portion of the valve assembly.
The valve spring is made from a brass alloy. The 2 3/4-in. valves (for 4 1/2- to 20-in. casing)
and the 4 1/4-in. valves (for 7-in. and larger casing) are rubber-coated to prevent erosion. The
2 3/4-in. valve is rated for flow rates of 10 bbl/min for 24 hours. The 4 1/4-in. valve is rated at
25 bbl/min for 24 hours. Tubing-size Super Seal™ II floating equipment with a 2 1/4-in. valve
has been tested at 6 bbl/min for 24 hours. All Halliburton Super Seal™ II floating equipment
exceeds the flow durability and pressure/temperature requirements established by API
RP-10F III C.
All casing-size Super Seal™ II float shoes and collars are supplied with an autofill feature
(at no additional cost). Because of size limitations, tubing-size Super Seal™ II floating
equipment is not supplied with an autofill strap. Customers can
request Super Seal™ II floating equipment for any casing grade or
premium thread.
Super Seal™ II Down-Jet Float Shoe
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
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
remove cuttings and filter cake, creating turbulence around the shoe,
and improving 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 blocked in the
event that casing is landed on the bottom of the hole.
Super Seal™ II Nonrotating (NR) Float Collar
Super Seal™ II nonrotating (NR) float collars offer all the features
of standard Super Seal™ II float collars, but they are equipped with a
NR plug seat that allows NR cementing plugs with locking teeth to
latch together during drillout. When these NR plastic plugs are
drilled out with PDC bits, they can reduce drillout time by 90%. This
equipment is available only with the 2 3/4- and 4 1/4-in. Super Seal™
II valve for 7- to 20-in. casing.
Halliburton Super Seal™ II
Down-Jet Float Shoe
Halliburton Super Seal™ II
Nonrotating Float Collar
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Halliburton Energy Services, Inc.
Super Seal™ II High-Port Up-Jet (HPUJ)
Float Shoe
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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 valve allow turbulent flow at the
shoe without damaging the float valve.
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 removes mud cake from the
formation face. Field reports indicate that the HPUJ float shoe
can substantially reduce the number of casing strings requiring
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 fill automatically with wellbore fluid
while it is being run in the hole, saving time and reducing the
“ram effect” of running casing.
Double-Valve Super Seal™ II
Floating Equipment
The double-valve Super Seal™ II float collars and float shoes
offer a double float valve, which is more economical than a
conventional float shoe and float collar. The double float valve
ensures a backpressure seal if one of the valves is damaged by
wellbore fluids or if debris between the valve and the valve
seat prevents the valve from sealing.
Halliburton Double-Valve Super Seal™ II
Float Shoe and Collar
The double-valve floating equipment has the following
features:
• a 2 3/4-in. valve for 5-in. and larger casing
• a 4 1/4-in. valve for 7-in. and larger casing
• several standard Super Seal™ II options, such as innerstring options, nonrotating inserts, and high-port up-jets
• availability in different casing grades and premium
threads
Double-valve Super Seal™ II float shoes and collars are
supplied with the autofill feature preset in the fill position.
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Halliburton Energy Services, Inc.
Super Seal™ II Tubing-Size Floating Equipment
Super Seal™ II tubing-size floating equipment is available
in both standard and HPUJ designs. Tubing-size float shoes
and collars prevent cement backflow from entering the tubing
string. Because of size restrictions, autofill devices are not
provided with tubing-size floating equipment. The case
material for all standard sizes and grades of equipment is
L-80 grade steel. Other material grades and premium threads
are available by special order. The 2 3/8-in. float shoe and float
collar includes the Super Seal™ 2 1/8-in. valve. Standard float
shoes and HPUJ float shoes are available in 2 7/8-in. and
3 1/2-in. tubing sizes. Tubing-size floating equipment should
be drilled out with roller-cone rock bits.
Super Seal™ II Float Shoe
The Super Seal™ II standard float shoe attaches to the lower
end of the casing string. This float shoe includes the Super
Seal™ II backpressure valve assembly, which prevents
cement in the annulus 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 roller-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.
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 after
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 feature (at no
additional cost). This feature, which is installed between the
valve and pressure seat, is deactivated by flow rate. The
autofill 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 autofill
feature is pumped loose with a high fluid rate, the float valve
is returned to a dependable Super Seal™ II backpressure
valve. The autofill feature will deactivate if the flow through
the valve reaches a predetermined rate (4 to 6 bbl/min for the
2 3/4-in. valve and 6 to 8 bbl/min for the 4 1/4-in. valve).
Halliburton Super Seal™ II Tubing-Size
Float Shoe and Collar
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Halliburton Super Seal™ II Float Collar
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Halliburton Energy Services, Inc.
Pressure Differential Fill (PDF)
Float Shoes and Collars
The pressure differential fill (PDF) float shoe and collar include a
convertible float valve. This valve allows casing to fill 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.
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 option. After the ball passes the float collar and/or shoe, the
PDF flapper closes against its seat, preventing cement from reentering the casing ID.
The PDF floating equipment is supplied in either a float collar or a
float shoe in common casing sizes. 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
/2 to 6 5/8 in. require a 1 3/8-in. diameter ball, while tools 7 in. and
larger require a 2 3/8-in. diameter ball.
Halliburton Pressure Differential Fill (PDF)
Float Shoe and Collar
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.
Insert Float Valve
Halliburton Insert
Float Valve Self-Fill Unit
The insert 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 float valve is used for casing flotation and
cementing operations in wells with moderate temperature and depth.
It can be used for differential pressures up to the collapse pressure of
the lightest weight of J-55 casing in the casing size in which it is run.
The insert float valve can be installed in long or short API 8-rd or
buttress casing couplings. Because of limited space between the
casing box and pin, insert float valves are not available for premiumthread casing. One or more insert valves can be run in a casing string
or in conjunction with a guide shoe.
Because they are made from aluminum, insert float-valve assemblies can be drilled out easily with a medium-tooth, roller-cone rock
bit. PDC bits should not be used to drill out insert valves.
Halliburton Insert Float Valve
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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 ball and plastic orifice
tube. The orifice tube holds the flapper open until a weighted plastic
ball is dropped into the casing. Once the ball reaches the ball seat,
pressure is applied to shear out the plastic orifice tube, which allows
the valve to close. This equipment operates efficiently in mud
systems containing high concentrations of lost-circulation material.
Halliburton Energy Services, Inc.
Guide Shoes
Guide shoes and down-jet guide shoes have the following
primary purposes:
• They protect the casing string from the impact 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 rounded nose of these guide shoes is made
from high-strength cement that can be drilled out easily with
roller-cone rock bits or PDC bits.
Halliburton Guide Shoe
Down-jet guide shoes have additional side ports in the steel
case that allow fluid to discharge through both the cement
nose and the ports. The jetting action of the fluid pumped
through these ports helps remove wellbore cuttings and filter
cake.
Workstring
Bit guide (Helps bit
re-enter casing
before drillout)
Load-Carrying Float Equipment
Load-carrying float equipment provides the following
advantages:
• It supports large-diameter casing and scab liners.
• It eliminates large-diameter plug containers.
• It enables the operator to reciprocate large-diameter
casing during a cement job.
• It is easily drilled with standard rock bits; no mill is
required.
• There is no cast iron to be drilled out.
Load-carrying float equipment is special, high-strength
inner-string cementing equipment designed to transfer
casing weight to the drillpipe through the float equipment.
This transfer is made possible with float equipment that has
an internally threaded receptacle that can be connected to an
adapter on the workstring. This connection allows the casing
load (up to 400,000 lb) to be transferred to the workstring.
After the large-diameter casing or scab liner is cemented, the
workstring is rotated several turns clockwise to disconnect it
from the casing or liner. Load-carrying float equipment and
bit guides for centralizing the top of the scab liner are
available in all casing sizes.
Halliburton Down-Jet
Guide Shoe
Drillpipe centralizer
Casing being
cemented
Load-carrying
sealing adapter
Load-carrying
Super Seal™ II
float equipment
Load-Carrying Float
Equipment
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Halliburton Energy Services, Inc.
Inner-String Cementing Equipment
Inner-string cementing equipment allows large-diameter casing strings to be cemented through
drillpipe or tubing that is inserted and sealed in floating equipment. Inner-string cementing has the
following advantages:
• It can be less costly than cementing large casing with the conventional plug-displacement
method.
• It does not require large-diameter cementing plugs.
• It reduces cement contamination.
• It reduces the amount of cement that has to be drilled out of large-diameter casing.
• It decreases cementing displacement time.
• It reduces casing collapse when surface packoff is used.
Inner-string cementing requires installation of a stab-in float
shoe or float collar in the casing string. The casing string is
run into the well in the usual manner. The inner string is then
run in, with the sealing adapter made up on the lower end
and stabbed into the floating-equipment sealing sleeve.
Halliburton Super Seal™ II
Float Collar with Sealing Sleeve
The sealing sleeve is built into the floating equipment to
provide a sealing-sleeve/bore receptacle for the inner-string
sealing adapter. Concrete is molded around the sealing
sleeve to secure the sleeve within the floating equipment.
The floating-equipment top is also tapered to form a surface
that helps guide the sealing-sleeve adapter into its sealing
sleeve. Two centralizers should be run on the inner string:
one centralizer directly above the sealing adapter, and
another one joint above the first centralizer. This arrangement will help the inner string enter the stab-in floating
equipment.
After the inner string (usually drillpipe) has been stabbed
into the floating equipment, cement is pumped through the
inner string and floating equipment into the casing/wellbore
annulus. After cementing has been completed, the check
valve in the floating equipment prevents cement from reentering the casing, and the sealing adapter and inner string
can be pulled from the casing.
Halliburton Super Seal™ II Float Collar
with Sealing Sleeve and Latchdown Plug
Floating equipment with a latchdown plug seat is also
available. This floating equipment is built with a combination sealing sleeve and latchdown plug seat. The combination sleeve, which is held in place by concrete, provides
(1) a sealing surface for the inner-string sealing adapter on
the top and (2) a bore configuration to latch and seal the
nose of a latchdown plug on bottom. After the last cement is
displaced down the inner string, a top latchdown cement
plug is launched down the inner string. The nose of the
latchdown plug seats and latches into the float equipment
sleeve immediately after passing through the inner-string
sealing sleeve. After latching in, the plug nose provides a
seal and withstands pressure from above and below.
After the inner string is retrieved, the latchdown plug serves as a backup to any backpressure valves
located in the casing string below. Pressure can be applied inside the casing immediately after the
latchdown plug has been landed and the sealing-sleeve adapter has been pulled from the sealing
sleeve.
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Halliburton Energy Services, Inc.
Casing string
Centralizer
Sealing sleeve
adapter
Super Seal™ II
float collar
Sealing sleeve
Super Seal™ II
float shoe
Halliburton Inner-String Cementing Method
without Top Cementing Latchdown Plug
Halliburton Inner-String Cementing Method
with Top Cementing Latchdown Plug
(Cementing Completed, Top Plug Latched,
and Inner String Being Pulled)
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Halliburton Energy Services, Inc.
Cementing Plugs
Cementing plugs are normally used during cementing operations to cement casing in a wellbore. They
offer the following advantages:
• They wipe mud sheath from the casing ID.
• They separate cement from wellbore fluids during cementing operations.
• They help prevent overdisplacement of cement slurry.
• They provide a surface indication when the cementing job is complete.
• High-pressure cementing plugs allow casing to be pressure-tested immediately after cement
displacement and before checking floats.
Standard Five-Wiper
Cementing Plugs
The five-wiper cementing plug is Halliburton’s primary
cementing plug. Five-wiper plugs are available in 4 1/2through 20-in. casing sizes with standard plastic and
aluminum inserts as well as 24-tooth nonrotating (NR)
plastic inserts.
Halliburton Standard Five-Wiper Cementing Plugs
Standard five-wiper cementing plugs are manufactured with
plastic and aluminum inserts. Aluminum inserts increase the
strength and temperature ratings of the plugs. These inserts
should be used when the bottomhole circulating temperature
(BHCT) exceeds 300°F. They should be drilled out with
conventional roller-cone rock bits. The recommended
landing pressures for aluminum-insert five-wiper plugs vary
depending on casing size, but they are normally higher than
the recommended landing pressures for wiper plugs with
plastic inserts. Five-wiper plugs are designed to land and
seal on Super Seal™ II floating equipment. These plugs
should not be used on floating equipment with tapered tops.
Plastic-insert plugs can be used in wells with BHCTs below
300°F. After cementing operations, the plastic-insert plugs
can be drilled out easily with roller-cone rock or PDC bits.
Halliburton Nonrotating (NR) Cementing Plugs
Standard five-wiper cementing plugs are available in either
standard or oil-resistant versions.
Nonrotating (NR) Cementing Plugs
Designed for use with Super Seal™ II nonrotating (NR)
float collars, top and bottom nonrotating (NR) plugs have
locking teeth that prevent the equipment from spinning
during drillout, which reduces drillout times and associated
rig costs. The high-strength plastic inserts used in NR plugs
increase plug-landing pressures and allow easy drillout with
both PDC and roller-cone rock bits. NR plugs are available
for 7- to 20-in. casing sizes. All NR plugs are made of a
synthetic service compound that is compatible with all
water-based and synthetic mud systems. Five-wiper highstrength NR cementing plugs can be used with highstrength float collars to pressure-test casing immediately
after cementing operations are completed.
Casing and tubing latchdown plugs and baffles are also
available in all common casing and tubing sizes.
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Halliburton Energy Services, Inc.
Subsurface Release (SSR)®
Cementing Plug System
The subsurface release (SSR)® cementing plug system
allows cementing operations to be performed from a floating
vessel or fixed platform that uses a subsea wellhead. The
SSR cementing plug set is installed in the top joint of the
casing string and is made up to the bottom of an installation
tool that is attached to the casing string. The installation tool
and casing string are lowered on a drillpipe string, landed
and sealed in the subsea wellhead on the ocean floor. When
the tool and string have landed, the well can be circulated
before cementing operations.
Bottom Plug
Releasing Ball
Top Plug
Releasing Dart
The bottom SSR plug is released ahead of the cement by a
weighted plastic ball dropped down the drillstring. The ball
lands on a seat of the bottom plug, releasing the bottom SSR
casing plug. When the bottom SSR plug lands on the float
collar, a bypass mechanism allows the cement to pump
around the ball.
After all the cement has been mixed and pumped into the
drillpipe, a drillpipe releasing dart is launched from the
surface to wipe the drillpipe ID and release the top SSR
casing plug. The drillpipe plug latches and seals in the top
SSR plug. The top SSR plug is then pumped to a pressure
shutoff on the float collar.
Standard SSR plugs and NR SSR plugs are available in top
or top-and-bottom plug sets for 7- to 20-in. casing sizes.
Drillpipe releasing darts are available for use with 4 1/2-, 5-,
5 1/2-, and 6 5/8-in. drillpipe sizes. NR plug sets are also
available for 9 5/8- by 10 3/4-in. combination casing strings.
Combination plug sets that meet individual requirements are
available on request. SSR plug sets are available with
aluminum, plastic, and composite plug inserts. Plastic and
composite plug sets can be drilled with standard/bi-center
PDC or rock bits, while aluminum insert plug sets should be
drilled only with roller-cone rock bits.
Top SSR plugs are available in standard and NR designs
from 7 in. through 20 in.
Halliburton Subsurface Release (SSR)
Cementing Plug System
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Halliburton Energy Services, Inc.
Multiple-Stage Cementing Tools
During multiple-stage cementing, cement slurry is placed at predetermined points around the casing
string in cementing stages. Multiple-stage cementing can be used for the following applications:
• cementing wells with low formation pressures that will not withstand the hydrostatic pressure of a
full column of cement
• cementing to isolate only certain sections of the wellbore
• placing different blends of cement in the wellbore
• cementing deep, hot holes where limited cement 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 the following 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 string
• drillability with either PDC or roller-cone rock bits
• compatibility with second-stage bottom plug sets
• external closing sleeve that is locked closed by the top cementing plug
• heavy-duty seals and backup rings that prevent seal damage during operations
• compatibility with three-stage cementing applications
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 than 30° 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 1/2- to 20-in. casing sizes. The
standard case material grade is L-80 steel. Other casing
grades and premium threads can be provided at the
customer’s request.
Halliburton Type-P External
Sleeve (ES) Cementer
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 prevent cement
overdisplacement around the shoe joint. After the firststage cementing operation is completed, 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. Fluid circulation 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 secondstage closing plug. The closing 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.
For information on stage tool plug sets, see Page 11.
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Halliburton Energy Services, Inc.
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.
When the first-stage cementing plug has seated, casing
pressure can be applied to hydraulically open the Type-H ES
cementer. Normally, the cementer 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 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 ES cementers are available in 4 1/2- to 20-in. casing
sizes. The standard material grade is L-80 grade steel. Other
grades and premium threads can be provided at the
customer’s request.
Halliburton Type-H External
Sleeve (ES) Cementer
Stage Tool Plug Sets
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.
A standard plug set for two-stage cementing consists of the
following equipment:
• a shutoff baffle installed on top of the float collar
(for 8-rd and buttress)
• 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)
• a baffle adapter installed one or more joints above the
float collar (for the Type-H cementer)
Use of a baffle adapter is necessary when using a
Type-H cementer with a first-stage bottom plug.
Halliburton Stage Tool Free-Fall Plug Set
with Insert Baffle
Halliburton Stage Tool Free-Fall Plug Set
with Baffle Adapter
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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Halliburton Energy Services, Inc.
Full-Opening (FO)
Multiple-Stage Cementer
The full-opening (FO) multiple-stage cementer is used to place
an indefinite number of cement stages or other fluids at
selected points along the outside of a casing string. An indefinite number of FO cementers can be run in the casing string.
The standard material grade is L-80. Other grades can be
supplied at the customer’s request.
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.
Halliburton Full-Opening (FO)
Multiple-Stage 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.
• 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 the same 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.
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 minimum hole size.
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Halliburton Energy Services, Inc.
External Sleeve Inflatable
Packer Collar (ESIPC)
The external sleeve inflatable packer collar (ESIPC) is a
combination of the ES (Type P or Type H) 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 above an 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 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 minimum hole size.
ESIPC’s are operated with standard stage tool plug sets.
Halliburton External Sleeve Inflatable
Packer Collar (ESIPC)—Type H
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Halliburton Energy Services, Inc.
Type-H Selective-Release (SR) Plug Set
The Type-H selective-release (SR) plug set is used during
two-stage cementing of a liner that contains a Type-H ES
cementer. The plug set consists of an SR first-stage shutoff
and closing plug that is normally installed on the bottom of
the stinger of a liner-setting tool, which is attached to the top
joint of the liner. However, if the liner-setting tool must be
disconnected from the liner before cementing, the SR plug
set must be installed on a launching collar located on the top
joint of the liner. If a hydraulically set liner hanger requiring
a ball-setting sub will be used, the ball-setting sub must be
placed in the casing string above the float collar and below
the baffle adapter. The ball-setting sub must retain the ball
when used with Super Seal IITM floating equipment.
Closing Plug
Releasing Dart
Shut-Off Plug
Releasing Dart
Halliburton Selective-Release (SR) Plug Set
14
After the liner hanger is set, the first-stage cement is pumped
through the drillpipe, followed by a drillpipe/releasing dart
that latches into and releases the lower SR shutoff plug. The
SR shutoff plug is pumped through the ID of the liner to
land and shut off on the baffle adapter. Drillpipe pressure
applied to the shutoff plug hydraulically opens the Type-H
cementer. The second-stage cement is mixed and pumped
down the drillpipe, followed by a second drillpipe dart. The
drillpipe/releasing dart latches into and releases the SR
closing plug. The SR closing plug is pumped through the
liner ID and lands in the Type-H cementer. Casing pressure
is applied to close the cementer. After cementing operations
are complete, the drillpipe is retrieved to the surface, and all
SR plugs are drilled out.
Halliburton Energy Services, Inc.
Formation Packer Shoes/Collars
A formation packer shoe or collar, which is installed on the casing string, is used when casing will be
set in a vertical hole on top of a predrilled low-pressure formation. A mechanical packer element seals
the annulus between the casing and the wellbore, allowing cement to be pumped into the annulus
above the packer element. Formation packer shoes/collars are available in two types: 852 series
(poppet valve) and 855 series (flapper valve). The 855 series is supplied as a float shoe and can be
converted to a collar when the float-shoe nose is removed.
852-Series Formation
Packer Shoe/Collar
The 852-series formation packer shoe/collar has a
double-poppet float valve that allows the casing to be
floated in the hole. However, this tool does not allow
automatic casing fill while casing is run in the hole.
The inverted check valve at the bottom of the tool
allows well fluids to be circulated at any time before
the packer is set. When the tool’s packer element is
ready to be set, a weighted plastic ball (2-in. OD for a
4 1/2- to 5-in. tool, 2 3/8-in. OD for a 5 1/2-in. or larger
tool) is dropped in the casing ID, falling by its own
weight to a seat in the tool. Pressure is applied to the
casing, shifting the tool’s valve mechanism downward, closing the bottom circulating port and expanding the packer element to seal against the wellbore.
After a pressure of 1,000 psi is applied to the casing,
the setting ball extrudes through the ball seat, allowing
fluid to be pumped into the casing/wellbore annulus
above the set packer element. The maximum recommended differential pressure across the packer element is 1,000 psi at temperatures below 200°F.
Cement is mixed and pumped into the annulus,
followed by a top cementing plug. The top cementing
plug is pumped to a pressure shutoff on top of the
tool. After cementing operations, the top cementing
plug and the tool’s internal components can be drilled
out. The 852-series formation packer shoe/collar
should not be run above a gas zone.
Halliburton 852-Series Formation Packer Shoe
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Halliburton Energy Services, Inc.
855-Series Formation Packer Shoe/Collar
The 855-series formation packer shoe/collar includes a flappertype float valve that allows the casing to be floated in the hole.
If desired, an orifice tube fill-up unit can be installed in the tool,
allowing casing to be filled while it is run in the hole.
A setting ball (which is used to set the tool’s packer element)
and a latchdown plug and baffle are packaged with each tool
assembly. The latchdown plug and baffle must be installed in
the casing above the formation packer shoe/collar because the
tool does not contain a backpressure valve to keep cement in
place in the annulus after cementing operations.
After the casing has been run to the desired depth, a weighted
plastic ball (2 1/4-in. OD for a 4 1/2-in. tool and 2 3/8-in. OD for a
5 1/2- or 7-in. tool) is dropped in the casing ID where it lands on
a seat in the tool. Pressure applied to the casing shifts the inner
sleeve of the tool downward, expanding the packer element so
that it seals against the wellbore. After 1,200 psi of pressure is
applied to the casing, cementing ports above the packer element
are exposed, allowing fluid to be pumped into the casing/
wellbore annulus above the set packer element. Cement is then
pumped into the annulus, followed by the top cementing
latchdown plug. The latchdown plug seats and seals in the
casing baffle, preventing cement from re-entering the casing
ID. After cementing operations, the latchdown plug, baffle, and
internal components of the formation packer shoe/collar can be
drilled out.
Halliburton 855-Series Formation Packer Shoe
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Halliburton Energy Services, Inc.
Super-Fill™ Equipment
Super-Fill™ equipment provides a reliable way for wellbore fluid to enter the casing or liner ID while
the casing is being run into the hole, thereby reducing the effective wellbore surge pressure and
reducing the volume of fluid lost to the formation.
Super-Fill™ equipment can be used for the following applications:
• on conventional full-bore casing
• near the bottom of a tieback casing string (run above the tieback stinger)
• on subsea completions
• when a liner is run and cemented in the wellbore
Super-Fill™ Collar
In a full-bore casing string, the Super-Fill™ collar is run in
the open position directly above the float collar. When casing
is run in the wellbore, fluid bypasses the float shoe and
collar, automatically filling the casing with wellbore fluid.
After the casing reaches the required setting depth, a standard five-wiper bottom cementing plug can be pumped down
the casing to land on and close the Super-Fill™ collar ports.
When these ports are closed, circulation fluid is diverted
through the float collar and float shoe and into the casing/
wellbore annulus. Cementing operations can then be performed in the conventional manner with standard top and
bottom cementing plugs.
A Super-Fill™ Type TB collar can also be used when a
production liner has been set in the wellbore and a tieback
casing string will be installed back to the surface. During
tieback applications, the Super-Fill™ Type TB collar is
installed in the open position immediately above the polished
bore receptacle (PBR) stinger. When the PBR stinger of the
tieback string is stabbed into the PBR, operators can cement
the tieback string without withdrawing the tieback from the
PBR.
The open ports of the Super-Fill™ collar (1) prevent a
“hydraulic lock” from occurring between the PBR stinger
and the PBR and (2) reduce the risk of damage to the stinger
seals when the stinger is reinserted in the PBR. The SuperFill™ collar can also be used in tight annular clearances
where tieback movement may be impossible after cement
placement. During tieback cementing operations, the top
cementing plug pumped behind the cement lands on the
Super-Fill™ collar plug seat. Casing pressure applied to the
top plug shears the pins in the tool, allowing the internal
sleeve to shift down and permanently cover the Super-Fill™
ports. After cementing operations, the top plug and internal
seats of the Super-Fill™ collar are drilled out with a PDC or
roller-cone rock bit.
Halliburton Super-Fill™ Collar with
Super Seal™ II Valve
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Halliburton Energy Services, Inc.
Super-Fill™ Diverter Tool
The Super-Fill™ diverter tool is used on subsea or liner
completions in which cementing operations are performed
through drillpipe. During these applications, the small annular
clearance between the previously cemented casing string or
hole diameter (liner application) prevents adequate mudflow
between the liner or casing being run and the previous casing
string. These small annular clearances cause high mud losses to
formations in the openhole section of the wellbore. A SuperFill™ collar installed on the lower end of the liner or casing
allows the wellbore fluid to enter the liner or casing freely, and
the Super-Fill™ diverter tool installed in the drillpipe string
allows the fluid to exit the drillpipe directly above the liner.
This arrangement reduces the pressure drop and the surge
pressure on the formation when the liner or casing is being run,
reducing mud loss into the formation.
The Super-Fill™ diverter tool consists of a ported inner
mandrel and an outer free-floating sleeve with drag springs.
The inner mandrel contains a J-slot mechanism that allows the
tool to open or close when the drillstring moves vertically.
Before cementing operations, the diverter tool can be permanently locked in the closed position by moving the drillpipe
upward while applying right-hand torque to the drillpipe.
Halliburton Super-Fill™ Diverter Tool
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Halliburton Energy Services, Inc.
Bow-Spring Centralizers
Bow-spring centralizers help center the casing in the 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 and nonwelded, provide the following advantages:
• They help center the casing in the wellbore, allowing even distribution of cement around the casing.
• They help reduce casing drag on the wellbore during casing running operations.
• They help prevent differential sticking of the casing.
• They increase fluid turbulence at the tool, helping remove filter cake from the wellbore.
• They can be run through hole restrictions in the 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 end rings, 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.
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 1/2 in. smaller than the centralizer’s nominal OD.
When run in holes less than 1/2 in. smaller than the OD, the
center of the centralizer contacts the casing OD, performing
as a rigid centralizer. Because of its high restoring force with
very little spring deflection, the dual-contact centralizer is
excellent for deviated and horizontal wellbores. The dualcontact centralizer should only be installed between a collar
and stop ring—never over a casing collar.
Halliburton
Welded Bow-Spring
Centralizer
Halliburton
Dual-Contact
Centralizer
Halliburton
Nonwelded Bow-Spring
Centralizer
Halliburton
Welded Centralizer
with Turbofins
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 are
supplied 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.
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 to more
evenly distribute cement around the casing.
All welded and nonwelded bowspring centralizers are
available in most common hole/casing sizes.
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Halliburton Cementing
Casing Equipment
and Accessories
Sales of Halliburton products and services will be in accord solely with the terms and conditions
contained in the contract between Halliburton and the customer that is applicable to the sale.
www.halliburton.com
®
2001 Halliburton Energy Services
Printed in U.S.A.