HES Casing Accessories Cat

Sales of Halliburton products and services will be in accord solely with the terms and conditionscontained in the contract between Halliburton and the customer that is applicable to the sale.

Printed in U.S.A.

Halliburton CementingCasing Equipmentand Accessories

www.halliburton.com ®2001 Halliburton Energy Services

Halliburton CementingCasing Equipment

and Accessories

i

Halliburton Energy Services, Inc.

Floating and Guiding Equipment ............................ 1Super Seal™ II Floating Equipment ............................................. 1

Super Seal™ II Down-Jet Float Shoe.................................... 1Super Seal™ II Nonrotating (NR) Float Collar ....................... 1Super Seal™ II High-Port Up-Jet Float Shoe ........................ 2Double-Valve Super Seal™ II Floating Equipment ................ 2Super Seal™ II Tubing-Size Floating Equipment .................. 3Super Seal™ II Float Shoe.................................................... 3Super Seal™ II Float Collar ................................................... 3

Pressure Differential Fill (PDF) Float Shoes and Collars ............. 4Insert Float Valve ......................................................................... 4Guide Shoes ................................................................................ 5Load-Carrying Float Equipment ................................................... 5

Inner-String Cementing Equipment ........................ 6

Cementing Plugs ...................................................... 8Standard Five-Wiper Cementing Plugs ................................. 8Nonrotating (NR) Cementing Plugs ....................................... 8Subsurface Release (SSR)® Cementing Plug System .......... 9

Multiple-Stage Cementing Tools ........................... 10Type-P External Sleeve (ES) Cementer .............................. 10Type-H External Sleeve (ES) Cementer ...............................11Stage Tool Plug Sets ............................................................11Full-Opening (FO) Multiple-Stage Cementer ....................... 12External Sleeve Inflatable Packer Collar (ESIPC) ............... 13Type-H Selective-Release (SR) Plug Set ............................ 14

Formation Packer Shoes/Collars .......................... 15852-Series Formation Packer Shoe/Collar .......................... 15855-Series Formation Packer Shoe/Collar .......................... 16

Super-Fill™ Equipment .......................................... 17Super-Fill™ Collar ............................................................... 17Super-Fill™ Diverter Tool .................................................... 18

Bow-Spring Centralizers........................................ 19Welded Bow-Spring Centralizer .......................................... 19Nonwelded Bow-Spring Centralizer ..................................... 19

1


Floating and Guiding EquipmentSuper Seal™ II Floating EquipmentSuper Seal™ II floating equipment is installed in the casing string and becomes an integralpart of the casing string. This equipment helps float and cement the casing in the well. Theequipment’s basic backpressure and temperature ratings (5,000 psi and 400°F) allow it to beused in most wells. The plastic valve materials and surrounding shear- and shockload-resistant concrete exceed the strength requirements for landing cementing plugs. The valveassembly and the cement holding the valve assembly in place can be drilled out easily withroller-cone rock bits or polycrystalline diamond compact (PDC) bits after cementing opera-tions. 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. The2 3/4-in. valve is rated for flow rates of 10 bbl/min for 24 hours. The 4 1/4-in. valve is rated at25 bbl/min for 24 hours. Tubing-size Super Seal™ II floating equipment with a 2 1/4-in. valvehas been tested at 6 bbl/min for 24 hours. All Halliburton Super Seal™ II floating equipmentexceeds the flow durability and pressure/temperature requirements established by APIRP-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 floatingequipment is not supplied with an autofill strap. Customers canrequest Super Seal™ II floating equipment for any casing grade orpremium thread.

Super Seal™ II Down-Jet Float ShoeThe Super Seal™ II down-jet float shoe includes the Super Seal™ IIfloat valve, which prevents cement backflow from re-entering thecasing ID. In addition to the center hole through the float valve, fourfluid ports are drilled in the outer case below the float valve. Theseports direct some of the fluid downward during circulation. Pressur-ized fluid jets out of the side ports and the guide nose, helpingremove 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 alternativecement flowpath if the bottom center port becomes blocked in theevent that casing is landed on the bottom of the hole.

Super Seal™ II Nonrotating (NR) Float CollarSuper Seal™ II nonrotating (NR) float collars offer all the featuresof standard Super Seal™ II float collars, but they are equipped with aNR plug seat that allows NR cementing plugs with locking teeth tolatch together during drillout. When these NR plastic plugs aredrilled out with PDC bits, they can reduce drillout time by 90%. Thisequipment 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™ IIDown-Jet Float Shoe

Halliburton Super Seal™ IINonrotating Float Collar

2


Halliburton Double-Valve Super Seal™ IIFloat Shoe and Collar

Super Seal™ II High-Port Up-Jet (HPUJ)Float ShoeThe High-Port Up-Jet (HPUJ) float shoe jets the formationface to remove detrimental mud cake and cuttings, increasingthe chances of a successful cement-to-formation bond. Thehigh circulation rates and cement flow rates that are possiblewith the Super Seal™ II float valve allow turbulent flow at theshoe without damaging the float valve.

The HPUJ shoe includes six fluid-discharge ports strategicallyplaced to jet the circulation fluid or cement upward, enhancingfluid turbulence far above the floating equipment. These up-jetports, along with four (or fewer) down-jet ports, distribute thefluid 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 ahigh velocity through the bottom of the float shoe, removingmaterial in its path and helping maneuver the casing pastledges and tight sections of the wellbore.

If the casing string is reciprocated during cementing, cementjetted through the exit ports removes mud cake from theformation face. Field reports indicate that the HPUJ float shoecan substantially reduce the number of casing strings requiringsqueeze cementing operations. All casing sizes of the SuperSeal™ II HPUJ float shoe use the same autofill strap used forthe Super Seal™ II float valve. When engaged, this strapallows the casing to fill automatically with wellbore fluidwhile it is being run in the hole, saving time and reducing the“ram effect” of running casing.

Double-Valve Super Seal™ IIFloating EquipmentThe double-valve Super Seal™ II float collars and float shoesoffer a double float valve, which is more economical than aconventional float shoe and float collar. The double float valveensures a backpressure seal if one of the valves is damaged bywellbore fluids or if debris between the valve and the valveseat prevents the valve from sealing.

The double-valve floating equipment has the followingfeatures:• 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 inner-

string 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 aresupplied with the autofill feature preset in the fill position.

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Halliburton Super Seal™ IIHigh-Port Up-Jet (HPUJ) Float Shoe

3


Super Seal™ II Tubing-Size Floating EquipmentSuper Seal™ II tubing-size floating equipment is availablein both standard and HPUJ designs. Tubing-size float shoesand collars prevent cement backflow from entering the tubingstring. Because of size restrictions, autofill devices are notprovided with tubing-size floating equipment. The casematerial for all standard sizes and grades of equipment isL-80 grade steel. Other material grades and premium threadsare available by special order. The 2 3/8-in. float shoe and floatcollar includes the Super Seal™ 2 1/8-in. valve. Standard floatshoes and HPUJ float shoes are available in 2 7/8-in. and3 1/2-in. tubing sizes. Tubing-size floating equipment shouldbe drilled out with roller-cone rock bits.

Super Seal™ II Float ShoeThe Super Seal™ II standard float shoe attaches to the lowerend of the casing string. This float shoe includes the SuperSeal™ II backpressure valve assembly, which preventscement in the annulus from re-entering the casing ID. Theplastic valve and stem materials are surrounded by drillableconcrete, making the equipment easy to drill out with PDCor roller-cone rock bits. The high-strength, durable roundednose safely guides the casing to the bottom of the hole. Thisequipment is available in all tubing and casing sizes withAPI 8-rd and buttress threads. The standard casing grade isK-55 material. Customers can request any casing grade andpremium thread by special order.

Super Seal™ II Float CollarThe Super Seal™ II float collar includes the Super Seal™ IIbackpressure valve, which prevents cement pumped into thecasing/wellbore annulus from re-entering the casing ID aftercementing operations. The float collar is normally installedone or two joints above the float or guide shoe. All casing-sizeSuper Seal™ II float collars include an autofill feature (at noadditional cost). This feature, which is installed between thevalve and pressure seat, is deactivated by flow rate. Theautofill feature allows wellbore fluids to enter the casing fromthe first joint, reducing surge pressure on the formation andreducing casing fill time from the surface. When the autofillfeature is pumped loose with a high fluid rate, the float valveis returned to a dependable Super Seal™ II backpressurevalve. The autofill feature will deactivate if the flow throughthe valve reaches a predetermined rate (4 to 6 bbl/min for the2 3/4-in. valve and 6 to 8 bbl/min for the 4 1/4-in. valve).

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Halliburton Super Seal™ II Tubing-SizeFloat Shoe and Collar

4


Halliburton InsertFloat Valve Self-Fill Unit

Halliburton Insert Float Valve

Pressure Differential Fill (PDF)Float Shoes and CollarsThe pressure differential fill (PDF) float shoe and collar include aconvertible float valve. This valve allows casing to fill while it isrun in the hole, and it allows fluid circulation at any time withoutdeactivating the fill unit. PDF float shoes and collars can be run inthe same casing string. They allow fluid to enter the bottom of thecasing while maintaining a constant differential pressure betweenthe inside and outside of the casing at the floats. This pressuremaintains a constant fluid height inside the casing.

PDF floating equipment is supplied in the differential-fill mode, andit is ready to be run in the hole. After all casing has been run, aweighted plastic ball is dropped in the casing from the surface andpumped through the tool. This procedure deactivates the differen-tial-fill option. After the ball passes the float collar and/or shoe, thePDF 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 afloat shoe in common casing sizes. All equipment run with thesetools must have an ID large enough to allow passage of theweighted ball that releases the backpressure valve. Tool sizes from 41/2 to 6 5/8 in. require a 1 3/8-in. diameter ball, while tools 7 in. andlarger require a 2 3/8-in. diameter ball.

PDF floating equipment should not be used in wells deviated morethan 30° from vertical, and it should not be drilled out with PDCbits. PDF equipment cannot be used with Super Seal™ II floatingequipment.

Insert Float ValveThe insert float valve is a backpressure check-valve assemblyinstalled between the pin and box ends of API 8-rd or buttress threadcasing joints. The insert float valve is used for casing flotation andcementing operations in wells with moderate temperature and depth.It can be used for differential pressures up to the collapse pressure ofthe 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 orbuttress casing couplings. Because of limited space between thecasing box and pin, insert float valves are not available for premium-thread casing. One or more insert valves can be run in a casing stringor in conjunction with a guide shoe.

Because they are made from aluminum, insert float-valve assem-blies can be drilled out easily with a medium-tooth, roller-cone rockbit. PDC bits should not be used to drill out insert valves.

The insert float valve has a large flow area and can be easilyconverted to autofill equipment if an orifice self-fill unit is installed.The self-fill unit includes a weighted plastic ball and plastic orificetube. The orifice tube holds the flapper open until a weighted plasticball is dropped into the casing. Once the ball reaches the ball seat,pressure is applied to shear out the plastic orifice tube, which allowsthe valve to close. This equipment operates efficiently in mudsystems containing high concentrations of lost-circulation material.

Halliburton Pressure Differential Fill (PDF)Float Shoe and Collar

5


Halliburton Guide Shoe

Guide ShoesGuide shoes and down-jet guide shoes have the followingprimary purposes:

• They protect the casing string from the impact associ-ated with landing casing on bottom.

• They direct casing away from ledges, reducing thechance of sidewall cave-in.

• They help casing pass through narrow, deviated holesand areas with hard shoulders.

The standard guide shoe has a large-ID hole through itscenter, allowing maximum cement pumping rates and thepassage of self-fill orifice tubes and balls dropped in thecasing string. The rounded nose of these guide shoes is madefrom high-strength cement that can be drilled out easily withroller-cone rock bits or PDC bits.

Down-jet guide shoes have additional side ports in the steelcase that allow fluid to discharge through both the cementnose and the ports. The jetting action of the fluid pumpedthrough these ports helps remove wellbore cuttings and filtercake.

Load-Carrying Float EquipmentLoad-carrying float equipment provides the followingadvantages:

• 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-strengthinner-string cementing equipment designed to transfercasing weight to the drillpipe through the float equipment.This transfer is made possible with float equipment that hasan internally threaded receptacle that can be connected to anadapter on the workstring. This connection allows the casingload (up to 400,000 lb) to be transferred to the workstring.After the large-diameter casing or scab liner is cemented, theworkstring is rotated several turns clockwise to disconnect itfrom the casing or liner. Load-carrying float equipment andbit guides for centralizing the top of the scab liner areavailable in all casing sizes.

Halliburton Down-JetGuide Shoe

Load-Carrying FloatEquipment

Workstring

Bit guide (Helps bitre-enter casingbefore drillout)

Drillpipe centralizer

Casing beingcementedLoad-carryingsealing adapter

Load-carryingSuper Seal IIfloat equipment

™

6


Halliburton Super Seal™ IIFloat Collar with Sealing Sleeve

Halliburton Super Seal™ II Float Collarwith Sealing Sleeve and Latchdown Plug

Inner-String Cementing EquipmentInner-string cementing equipment allows large-diameter casing strings to be cemented throughdrillpipe or tubing that is inserted and sealed in floating equipment. Inner-string cementing has thefollowing advantages:

• It can be less costly than cementing large casing with the conventional plug-displacementmethod.

• 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 floatshoe or float collar in the casing string. The casing string isrun into the well in the usual manner. The inner string is thenrun in, with the sealing adapter made up on the lower endand stabbed into the floating-equipment sealing sleeve.

The sealing sleeve is built into the floating equipment toprovide a sealing-sleeve/bore receptacle for the inner-stringsealing adapter. Concrete is molded around the sealingsleeve to secure the sleeve within the floating equipment.The floating-equipment top is also tapered to form a surfacethat helps guide the sealing-sleeve adapter into its sealingsleeve. Two centralizers should be run on the inner string:one centralizer directly above the sealing adapter, andanother one joint above the first centralizer. This arrange-ment will help the inner string enter the stab-in floatingequipment.

After the inner string (usually drillpipe) has been stabbedinto the floating equipment, cement is pumped through theinner string and floating equipment into the casing/wellboreannulus. After cementing has been completed, the checkvalve in the floating equipment prevents cement from re-entering the casing, and the sealing adapter and inner stringcan be pulled from the casing.

Floating equipment with a latchdown plug seat is alsoavailable. This floating equipment is built with a combina-tion sealing sleeve and latchdown plug seat. The combina-tion sleeve, which is held in place by concrete, provides(1) a sealing surface for the inner-string sealing adapter onthe top and (2) a bore configuration to latch and seal thenose of a latchdown plug on bottom. After the last cement isdisplaced down the inner string, a top latchdown cementplug is launched down the inner string. The nose of thelatchdown plug seats and latches into the float equipmentsleeve immediately after passing through the inner-stringsealing sleeve. After latching in, the plug nose provides aseal and withstands pressure from above and below.

After the inner string is retrieved, the latchdown plug serves as a backup to any backpressure valveslocated in the casing string below. Pressure can be applied inside the casing immediately after thelatchdown plug has been landed and the sealing-sleeve adapter has been pulled from the sealingsleeve.

7


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without Top Cementing Latchdown PlugHalliburton Inner-String Cementing Method

with Top Cementing Latchdown Plug(Cementing Completed, Top Plug Latched,

and Inner String Being Pulled)

Casing string

Centralizer

Sealing sleeveadapter

Sealing sleeve

Super Seal IIfloat collar

™

Super Seal IIfloat shoe

™

8


Cementing PlugsCementing plugs are normally used during cementing operations to cement casing in a wellbore. Theyoffer 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-WiperCementing PlugsThe five-wiper cementing plug is Halliburton’s primarycementing plug. Five-wiper plugs are available in 4 1/2-through 20-in. casing sizes with standard plastic andaluminum inserts as well as 24-tooth nonrotating (NR)plastic inserts.

Standard five-wiper cementing plugs are manufactured withplastic and aluminum inserts. Aluminum inserts increase thestrength and temperature ratings of the plugs. These insertsshould be used when the bottomhole circulating temperature(BHCT) exceeds 300°F. They should be drilled out withconventional roller-cone rock bits. The recommendedlanding pressures for aluminum-insert five-wiper plugs varydepending on casing size, but they are normally higher thanthe recommended landing pressures for wiper plugs withplastic inserts. Five-wiper plugs are designed to land andseal on Super Seal™ II floating equipment. These plugsshould not be used on floating equipment with tapered tops.

Plastic-insert plugs can be used in wells with BHCTs below300°F. After cementing operations, the plastic-insert plugscan be drilled out easily with roller-cone rock or PDC bits.

Standard five-wiper cementing plugs are available in eitherstandard or oil-resistant versions.

Nonrotating (NR) Cementing PlugsDesigned for use with Super Seal™ II nonrotating (NR)float collars, top and bottom nonrotating (NR) plugs havelocking teeth that prevent the equipment from spinningduring drillout, which reduces drillout times and associatedrig costs. The high-strength plastic inserts used in NR plugsincrease plug-landing pressures and allow easy drillout withboth PDC and roller-cone rock bits. NR plugs are availablefor 7- to 20-in. casing sizes. All NR plugs are made of asynthetic service compound that is compatible with allwater-based and synthetic mud systems. Five-wiper high-strength NR cementing plugs can be used with high-strength float collars to pressure-test casing immediatelyafter cementing operations are completed.

Casing and tubing latchdown plugs and baffles are alsoavailable in all common casing and tubing sizes.

Halliburton Standard Five-Wiper Cementing Plugs

Halliburton Nonrotating (NR) Cementing Plugs

9


Subsurface Release (SSR)®

Cementing Plug SystemThe subsurface release (SSR)® cementing plug systemallows cementing operations to be performed from a floatingvessel or fixed platform that uses a subsea wellhead. TheSSR cementing plug set is installed in the top joint of thecasing string and is made up to the bottom of an installationtool that is attached to the casing string. The installation tooland casing string are lowered on a drillpipe string, landedand sealed in the subsea wellhead on the ocean floor. Whenthe tool and string have landed, the well can be circulatedbefore cementing operations.

The bottom SSR plug is released ahead of the cement by aweighted plastic ball dropped down the drillstring. The balllands on a seat of the bottom plug, releasing the bottom SSRcasing plug. When the bottom SSR plug lands on the floatcollar, a bypass mechanism allows the cement to pumparound the ball.

After all the cement has been mixed and pumped into thedrillpipe, a drillpipe releasing dart is launched from thesurface to wipe the drillpipe ID and release the top SSRcasing plug. The drillpipe plug latches and seals in the topSSR plug. The top SSR plug is then pumped to a pressureshutoff on the float collar.

Standard SSR plugs and NR SSR plugs are available in topor 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 alsoavailable for 9 5/8- by 10 3/4-in. combination casing strings.Combination plug sets that meet individual requirements areavailable on request. SSR plug sets are available withaluminum, plastic, and composite plug inserts. Plastic andcomposite plug sets can be drilled with standard/bi-centerPDC or rock bits, while aluminum insert plug sets should bedrilled only with roller-cone rock bits.

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Halliburton Subsurface Release (SSR)Cementing Plug System

Bottom PlugReleasing Ball

Top PlugReleasing Dart

10


Halliburton Type-P ExternalSleeve (ES) Cementer

Multiple-Stage Cementing ToolsDuring multiple-stage cementing, cement slurry is placed at predetermined points around the casingstring 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 afull 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 openedstage 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) CementerType-P external sleeve (ES) cementers can be used in mostvertical wells, regardless of depth, pressure, or tempera-ture. The Type-P cementer should not be used in wellsdeviated more than 30° from vertical when using a free-fallopening plug. Otherwise, the free-fall opening plug willnot fall by its own weight through well casing. Type-P EScementers are available in 4 1/2- to 20-in. casing sizes. Thestandard case material grade is L-80 steel. Other casinggrades and premium threads can be provided at thecustomer’s request.

During cementing operations, the first-stage cement ismixed and pumped into the casing in a conventionalmanner. The first-stage shutoff plug, which is launched inthe casing after the first-stage cement, lands on the shutoffbaffle installed on the float collar. This shutoff plugprovides a positive shutoff, which helps prevent cementoverdisplacement around the shoe joint. After the first-stage cementing operation is completed, a free-fall openingplug is dropped down the casing ID to land and seal in thecementer. Pressure applied to the casing opens the ce-menter, allowing wellbore fluid to be pumped into thecasing/wellbore annulus. Fluid circulation to the surface isnormally maintained until the first-stage cement has set upin the annulus. The second-stage cement is then pumpedthrough the open cementer ports, followed by a second-stage closing plug. The closing plug seats in the cementer,and pressure is applied to the casing to close the tool. Afterboth stages are cemented, the cementer seats, and plugs aredrilled out with a rock bit or a PDC bit.

For information on stage tool plug sets, see Page 11.

11


Type-H External Sleeve (ES) CementerThe Type-H external sleeve (ES) cementer is a hydraulicallyopened stage cementer that can be used in most wells,regardless of depth, pressure, or temperature. Although theType-H ES cementer operates much like a Type-P cementer,it can be opened with internal casing pressure in addition tothe free-fall plug after the first-stage shutoff plug lands. Thisdesign feature saves time by eliminating the need for drop-ping a free-fall plug from the surface. A baffle adapter isrecommended in the casing string above the float collar toseat the first-stage shutoff plug.

When the first-stage cementing plug has seated, casingpressure can be applied to hydraulically open the Type-H EScementer. Normally, the cementer should be opened immedi-ately after the first-stage cement is pumped and the shutoffplug has been bumped. If the well is deviated less than 30°from vertical, the Type-H ES cementer can also be openedwith a free-fall plug dropped through the casing ID. TheType-H cementer can be used in highly deviated wells, inhorizontal wells, and above an openhole completion orslotted liner. After the second-stage cementing operation, asecond-stage closing plug pumped behind the second-stagecement closes the cementer. Lock rings in the externalclosing sleeve lock the cementer in the closed position. Afterboth cementing stages, the cementer seats, and plugs aredrilled out with a roller-cone rock bit or a PDC bit.

Type-H ES cementers are available in 4 1/2- to 20-in. casingsizes. The standard material grade is L-80 grade steel. Othergrades and premium threads can be provided at thecustomer’s request.

Stage Tool Plug SetsPlug sets for operating both Type-P and Type-H cementersmust be ordered separately from the cementer. The indi-vidual components of each plug set depend on the type oftool to be operated.

A standard plug set for two-stage cementing consists of thefollowing 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-Hcementers)

• a free-fall opening plug (required for the Type-Pcementer; optional for the Type-H cementer)

• a closing plug (for both Type-P and Type-Hcementers)

• a baffle adapter installed one or more joints above thefloat collar (for the Type-H cementer)Use of a baffle adapter is necessary when using aType-H cementer with a first-stage bottom plug.

Wells can also be cemented in three stages with two cement-ers and a three-stage plug set. A three-stage plug set must beordered separately from the cementers.

Halliburton Type-H ExternalSleeve (ES) Cementer

Halliburton Stage Tool Free-Fall Plug Setwith Insert Baffle

Halliburton Stage Tool Free-Fall Plug Setwith Baffle Adapter

12


Halliburton Full-Opening (FO)Multiple-Stage Cementer

Full-Opening (FO)Multiple-Stage CementerThe full-opening (FO) multiple-stage cementer is used to placean indefinite number of cement stages or other fluids atselected points along the outside of a casing string. An indefi-nite number of FO cementers can be run in the casing string.The standard material grade is L-80. Other grades can besupplied 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 conventionalmanner. All subsequent cementing stages are pumped througha workstring run inside the casing. Shifting tools run 8 to 10 ftapart on the workstring are used to open or close the FOcementer.

Unlike plug-operated or hydraulically opened stage cementers,FO cementers provide the following benefits:

• They do not require operating plugs, eliminating theneed for drilling out after cementing.

• FO cementers can be used to test, treat, and evaluate azone in the well before it is closed.

• Multiple FO cementers can be run in the same casingstring.

• Operators can open and close these tools as many timesas necessary.

A packoff between the workstring and casing is required todirect fluid out the open ports of the FO cementer.

FO cementers are available by special order for any casinggrade or premium thread. For pricing information, customersmust provide information about casing OD, thread type,weight, grade, and minimum hole size.

13


Halliburton External Sleeve InflatablePacker Collar (ESIPC)—Type H

External Sleeve InflatablePacker Collar (ESIPC)The external sleeve inflatable packer collar (ESIPC) is acombination of the ES (Type P or Type H) cementer and acasing inflation packer. This tool provides controlled packerelement inflation through the stage-tool opening seat,eliminating hydraulic valving bodies normally used withinflatable packer elements. The rubber inflatable packerelement is constructed with reinforcing metal slats to reducepacker element damage during inflation. This inflatablepacker element allows packer differential pressures up to4,000 psi.

The ESIPC is commonly used in horizontal well applicationsfor cementing casing in the bend radius or vertical portion ofthe wellbore above an openhole completion or a slotted liner.The packer element is inflated to prevent cement fromflowing downhole when it is pumped into the annulus abovethe tool.

The ESIPC is available by special order for any casing gradeor premium thread. For pricing information, customers mustprovide information about casing OD, thread type, weight,grade, and minimum hole size.

ESIPC’s are operated with standard stage tool plug sets.

14


Halliburton Selective-Release (SR) Plug Set

Closing PlugReleasing Dart

Shut-Off PlugReleasing Dart

Type-H Selective-Release (SR) Plug SetThe Type-H selective-release (SR) plug set is used duringtwo-stage cementing of a liner that contains a Type-H EScementer. The plug set consists of an SR first-stage shutoffand closing plug that is normally installed on the bottom ofthe stinger of a liner-setting tool, which is attached to the topjoint of the liner. However, if the liner-setting tool must bedisconnected from the liner before cementing, the SR plugset must be installed on a launching collar located on the topjoint of the liner. If a hydraulically set liner hanger requiringa ball-setting sub will be used, the ball-setting sub must beplaced in the casing string above the float collar and belowthe baffle adapter. The ball-setting sub must retain the ballwhen used with Super Seal IITM floating equipment.

After the liner hanger is set, the first-stage cement is pumpedthrough the drillpipe, followed by a drillpipe/releasing dartthat latches into and releases the lower SR shutoff plug. TheSR shutoff plug is pumped through the ID of the liner toland and shut off on the baffle adapter. Drillpipe pressureapplied to the shutoff plug hydraulically opens the Type-Hcementer. The second-stage cement is mixed and pumpeddown the drillpipe, followed by a second drillpipe dart. Thedrillpipe/releasing dart latches into and releases the SRclosing plug. The SR closing plug is pumped through theliner ID and lands in the Type-H cementer. Casing pressureis applied to close the cementer. After cementing operationsare complete, the drillpipe is retrieved to the surface, and allSR plugs are drilled out.

15


Formation Packer Shoes/CollarsA formation packer shoe or collar, which is installed on the casing string, is used when casing will beset in a vertical hole on top of a predrilled low-pressure formation. A mechanical packer element sealsthe annulus between the casing and the wellbore, allowing cement to be pumped into the annulusabove 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 beconverted to a collar when the float-shoe nose is removed.

852-Series FormationPacker Shoe/CollarThe 852-series formation packer shoe/collar has adouble-poppet float valve that allows the casing to befloated in the hole. However, this tool does not allowautomatic casing fill while casing is run in the hole.The inverted check valve at the bottom of the toolallows well fluids to be circulated at any time beforethe packer is set. When the tool’s packer element isready to be set, a weighted plastic ball (2-in. OD for a4 1/2- to 5-in. tool, 2 3/8-in. OD for a 5 1/2-in. or largertool) is dropped in the casing ID, falling by its ownweight to a seat in the tool. Pressure is applied to thecasing, shifting the tool’s valve mechanism down-ward, closing the bottom circulating port and expand-ing 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, allowingfluid to be pumped into the casing/wellbore annulusabove the set packer element. The maximum recom-mended differential pressure across the packer ele-ment 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 cementingplug is pumped to a pressure shutoff on top of thetool. After cementing operations, the top cementingplug and the tool’s internal components can be drilledout. The 852-series formation packer shoe/collarshould not be run above a gas zone.

Halliburton 852-Series Formation Packer Shoe

16


855-Series Formation Packer Shoe/CollarThe 855-series formation packer shoe/collar includes a flapper-type 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 toolassembly. The latchdown plug and baffle must be installed inthe casing above the formation packer shoe/collar because thetool does not contain a backpressure valve to keep cement inplace in the annulus after cementing operations.

After the casing has been run to the desired depth, a weightedplastic ball (2 1/4-in. OD for a 4 1/2-in. tool and 2 3/8-in. OD for a5 1/2- or 7-in. tool) is dropped in the casing ID where it lands ona seat in the tool. Pressure applied to the casing shifts the innersleeve of the tool downward, expanding the packer element sothat it seals against the wellbore. After 1,200 psi of pressure isapplied to the casing, cementing ports above the packer elementare exposed, allowing fluid to be pumped into the casing/wellbore annulus above the set packer element. Cement is thenpumped into the annulus, followed by the top cementinglatchdown plug. The latchdown plug seats and seals in thecasing baffle, preventing cement from re-entering the casingID. After cementing operations, the latchdown plug, baffle, andinternal components of the formation packer shoe/collar can bedrilled out.

Halliburton 855-Series Formation Packer Shoe

17


Super-Fill™ EquipmentSuper-Fill™ equipment provides a reliable way for wellbore fluid to enter the casing or liner ID whilethe casing is being run into the hole, thereby reducing the effective wellbore surge pressure andreducing 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™ CollarIn a full-bore casing string, the Super-Fill™ collar is run inthe open position directly above the float collar. When casingis run in the wellbore, fluid bypasses the float shoe andcollar, automatically filling the casing with wellbore fluid.After the casing reaches the required setting depth, a stan-dard five-wiper bottom cementing plug can be pumped downthe casing to land on and close the Super-Fill™ collar ports.When these ports are closed, circulation fluid is divertedthrough the float collar and float shoe and into the casing/wellbore annulus. Cementing operations can then be per-formed in the conventional manner with standard top andbottom cementing plugs.

A Super-Fill™ Type TB collar can also be used when aproduction liner has been set in the wellbore and a tiebackcasing string will be installed back to the surface. Duringtieback applications, the Super-Fill™ Type TB collar isinstalled in the open position immediately above the polishedbore receptacle (PBR) stinger. When the PBR stinger of thetieback string is stabbed into the PBR, operators can cementthe tieback string without withdrawing the tieback from thePBR.

The open ports of the Super-Fill™ collar (1) prevent a“hydraulic lock” from occurring between the PBR stingerand the PBR and (2) reduce the risk of damage to the stingerseals when the stinger is reinserted in the PBR. The Super-Fill™ collar can also be used in tight annular clearanceswhere tieback movement may be impossible after cementplacement. During tieback cementing operations, the topcementing plug pumped behind the cement lands on theSuper-Fill™ collar plug seat. Casing pressure applied to thetop plug shears the pins in the tool, allowing the internalsleeve to shift down and permanently cover the Super-Fill™ports. After cementing operations, the top plug and internalseats of the Super-Fill™ collar are drilled out with a PDC orroller-cone rock bit.

Halliburton Super-Fill™ Collar withSuper Seal™ II Valve

18


Halliburton Super-Fill™ Diverter Tool

Super-Fill™ Diverter ToolThe Super-Fill™ diverter tool is used on subsea or linercompletions in which cementing operations are performedthrough drillpipe. During these applications, the small annularclearance between the previously cemented casing string orhole diameter (liner application) prevents adequate mudflowbetween the liner or casing being run and the previous casingstring. These small annular clearances cause high mud losses toformations in the openhole section of the wellbore. A Super-Fill™ collar installed on the lower end of the liner or casingallows the wellbore fluid to enter the liner or casing freely, andthe Super-Fill™ diverter tool installed in the drillpipe stringallows the fluid to exit the drillpipe directly above the liner.This arrangement reduces the pressure drop and the surgepressure 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 innermandrel and an outer free-floating sleeve with drag springs.The inner mandrel contains a J-slot mechanism that allows thetool to open or close when the drillstring moves vertically.Before cementing operations, the diverter tool can be perma-nently locked in the closed position by moving the drillpipeupward while applying right-hand torque to the drillpipe.

19


Bow-Spring CentralizersBow-spring centralizers help center the casing in the wellbore during cementing operations, allowing thecement 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 casingOD. 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.

HalliburtonDual-ContactCentralizer

HalliburtonWelded Centralizer

with Turbofins

HalliburtonWelded Bow-Spring

Centralizer

HalliburtonNonwelded Bow-Spring

Centralizer

Welded Bow-Spring CentralizerWelded bow-spring centralizers are available in two styles:slip-on and hinged. Slip-on centralizers are manufacturedwith solid end rings, requiring the centralizer to be slippedon the casing OD during installation. Hinged centralizers aremanufactured in segments, allowing the centralizer to beinstalled easily around the casing OD. Hinge pins hold thesegments together during installation. All welded bow-springcentralizers are manufactured to API Specification 10D.

The dual-contact (double bow) welded centralizer is de-signed for small-clearance casing-to-hole size applications.The centralizer will perform as a standard bow centralizer inholes 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, thecenter of the centralizer contacts the casing OD, performingas a rigid centralizer. Because of its high restoring force withvery little spring deflection, the dual-contact centralizer isexcellent for deviated and horizontal wellbores. The dual-contact centralizer should only be installed between a collarand stop ring—never over a casing collar.

Nonwelded Bow-Spring CentralizerNonwelded bow-spring centralizers are available in thehinged style only. The bow springs of this centralizer areattached to the end rings without welding. The centralizerbow end is connected to the end rings with a locking tab thatbears the load force on the centralizer. The centralizers aresupplied in hinged segments joined by hinge pins in eachsegment. All nonwelded centralizers meet or exceed therequirements of API Specification 10D, which dictates theminimum restoring and maximum starting forces for central-izers for various casing/hole size combinations.

Centralizers with turbofins attached to each bow spring aredesigned to create localized turbulent fluid flow at thecentralizer. The turbofins divert the fluid flow to moreevenly distribute cement around the casing.

All welded and nonwelded bowspring centralizers areavailable in most common hole/casing sizes.

Sales of Halliburton products and services will be in accord solely with the terms and conditionscontained in the contract between Halliburton and the customer that is applicable to the sale.

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Halliburton CementingCasing Equipmentand Accessories

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HES Casing Accessories Cat

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