Casing Annulus Packers and Accessories

Casing AnnulusPackers andAccessories

• Stop Annular Gas Migration

• Multiple Stage Cementing

• One Trip–Cement the RadiusHorizontal Completions

• Zone Isolation

• Scab Liners

TAM

Inflatable and Swellable Packers

ISO 9001: 2008 Cert i f ied Company

Product ProfileTAM International manufactures and services one of the widest ranges of inflatable Casing Annulus Packers (CAPTM) and accessories. TAM products andservices enable more effective and efficient zone isolation in a wide spectrum of downhole conditionsand operational requirements.

TAM inflatable Casing Annulus Packers range from1.90-in. to 20-in. with seal lengths from 3-ft to 35-ft.TAM packer applications include a variety of drilling,completion and workover operations. In addition tostandard products as described in this brochure, TAMhas developed a reputation for designing, verifyingand manufacturing special customer-specific products.

What is a CAP?Casing Annulus Packers (CAP) are inflatable downhole tools installed on the outside diameter of a pupjoint of casing or casing mandrel. The CAP includesan inflation control valve mechanism to inflate theelement and create a seal between the casing man-drel and open hole or previously set casing string.

Why run a CAP?Casing Annulus Packers (CAP) are superior for a wide variety of applications where a seal is requiredbetween casing and open hole (or previous casingstring). Casing Annulus Packers can inflate to greaterthan 2.5 times their run-in diameters. Casing can bereciprocated with CAP in the string. The greatestadvantage is that Casing Annulus Packers enhancecustomer flexibility in planning a completion.

A CAP can be inflated by straddling the inflation portwith a variety of packer setting tools or by simplyapplying pressure to the entire casing string.

ISO 9001: 2008 CertifiedAll TAM locations provide quality service and thorough product support. Every customer inquiry iscarefully screened by a select team of professionals.Quality system guidelines certified to ISO 9001: 2008requirements are used to determine which jobs arepractical, proper tool selection and field procedures.

To assure product quality and reliable operations,Casing Annulus Packers undergo function testingbefore shipment. All components are traceable andeach product serialized in compliance with ISO require-ments down to the maintenance of electronic pressurerecordings of all tests with the serial number file.

Two Distinct CAP Constructions

TAMCAPTM and LONGCAPTM Construction

The TAMCAP and LONGCAP products use highstrength stainless steel slats to reinforce the fulllength of the inflatable element. TAMCAP andLONGCAP are available with standard 3-ft (0.9m)and 10-ft (3m) seal lengths. A pliable, oil-resistant elastomer covers the steel reinforcement for effectivesealing in open hole. One end of the packer elementslides while maintaining a seal to the casing mandrel.TAMCAP and LONGCAP best suit vertical well andlow build rate deviated well applications.

XTRACAPTM Construction

The XTRACAP product is partially reinforced withstainless steel slats extending 20-in. from each end of the inflatable element. The slats improve differentialpressure capacity and provide extrusion resistancefor the elastomer at elevated temperature.

The center section of the inflatable element is a pliable, oil-resistant elastomer bonded to the casingmandrel. The center section design reduces damagefrom drag loads exerted when passing through thebuild section of horizontal wells.

The XTRACAP is available with standard seallengths of 5-ft (1.5m), 10-ft (3m), 20-ft (6.1m) and 35-ft (10.7m). The XTRACAP is the standard productfor most horizontal and high Dogleg Severity deviated well applications.

COMMON CAP APPLICATIONS• For multiple stage cementing in vertical wells

Casing Annulus Packers are placed below the stagetool to support the cement column while it cures.

• To prevent annular gas migration, Casing Annulus Packers above the gas source stop the migration and ensure the integrity of the cement job.

• To separate horizontal wells into segments,slotted liner, screens and blank casing are selectivelyplaced between CAPs. The TAM XTRACAPTM is special-ly designed for zone isolation below the build section.

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CAP, SafeLok, TAMCAP, LONGCAP, XTRACAP &

XTRALONGCAP are trademarks of TAM INTERNATIONAL

Automatic Casing Annulus Packer Operation Sequence

General Running ProcedureCasing Annulus Packers make up into the casingstring using the same tongs and make up torque as the rest of the string. The casing tally and log correlation determine the correct location of theCAP in the string. Open hole caliper logs also aid in proper location of the CAP with respect tohole conditions.

The valve sub can be located on either end of the inflation element to run in the up or down position. The CAP is inflated by pressuring the casing ID eitheragainst a bumped plug or by straddling the inflationport with a Combination Tool. Applied pressure shearsthe Opening Valve shear pin. Inflation fluid expandsthe packer element until sufficient pressure inside theelement closes the Delta P Valve. Removing pressurefrom the casing ID activates the SafeLokTM (See page6) feature, permanently locking the Opening Valve inthe closed position.

No Weld One-Piece Mandrel DesignTAM constructs all Casing Annulus Packers using a one-piece casing mandrel with NO hidden internal connections. There is NO welding to the casing mandrelduring construction.

This one-piece mandrel construction allows TAM toprovide the longest mandrel length of any casing packer.

A long one-piece mandrel reduces side loads whenpassing through the build section. It also assures premium thread consistency throughout the string andoptimum casing physical, tensile and torsional properties.

Built-to-Order CAPMany customers supply premium threaded pup joints oftheir casing to TAM and the inflatable Casing AnnulusPackers are built on their pipe. This maintains completeintegrity and traceability in their string, especially forcritical well completions using exotic metals.

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TAM-C-TAMCAP 1/31/08 12:39 PM

Couplings are the sameas those on the rest ofthe casing string. Outer layer of

oil resistant elastomer.

Inflation fluid is pumpedbetween the casing mandreland the bladder.TAMCAP and LONGCAP are fully

stainless steel reinforced end-to-endand best suit vertical well and lowbuild rate deviated well applications.

TAM XTRACAP long one-piece mandrel construction reduces side loads when passing through build section.

Thick elastomer layerbonded to casing.

Full boreopeningthroughthe packer.

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Two Distinct CAP Constructions


The pliable center section of the XTRACAPadapts to the rugged contour of the open hole.

Overlapping steelreinforcement.

Casing mandrel 10 ft.longer than seal length

The TAM XTRACAP is partially steel reinforcedwith 20” stainless steel slats that extend from eachend. The center section of the inflatable element isa pliable oil resistant elastomer bonded to the casing mandrel.

Thick elastomer layer -bonded to casing.

Oil Resistant Elastomer

Casing Mandrel

Bladder

Steel Slats

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Multiple-layer, slat type construction (VE)


SafeLokTM Inflation Valve SystemThousands of difficult CAP installations prove theTAM SafeLok Inflation Valve System’s reliability. TAMuses a proprietary computer program to analyze down-hole conditions and recommend the proper Opening and

Delta P (closing) shear pins for any well application.TAM inflation valve systems can be run above orbelow the inflation element.

Locked Set PositionBy removing (bleeding) the applied pressurefrom the casing ID, the Opening Valvemechanically separates and permanentlylocks in the Closed position as shown in theLocked Set position drawing.

Inflating PositionAs shown in the Inflating position drawing,sufficient pressure applied to the casing IDshears the Opening Valve pin and initiatesinflation of the packer element.

Run-In PositionThis unique system consists of an OpeningValve (Normally Closed) and a Delta PValve (Normally Open) as shown in the RunIn position drawing. An optional break offrod extends into the casing ID to reducepremature plugging of the inlet ports.

Inflated (Set) PositionWhen proper inflation pressure isachieved as determined by a choice ofDelta P shear pins, the Delta P valvecloses and permanently locks closed byhydraulic forces. This step is shown inthe Inflated position drawing.

CAP Inflation Valves

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TAM has conducted extensive research on inflationfluid characteristics including water, mud, gases andcement to determine specific application selection.

TAM conducts ongoing research on the CAP productline to define the long-term effects of differential pres-sure and temperature changes downhole, torsion andtensile load variations and side loading when runningthrough high Dogleg Severity sections of horizontalwells. Research continues with the objective of fullyutilizing the CAP product to solve customer problems.

A complete computerized analysis is performed oneach CAP application, including the product’s ability:

• To pass through the maximum Dogleg Severity without damage to the CAP (horcomp.xls)

• To function at the bottom-hole conditions of the well(temperature, pressure, fluid exposure) (capsel.xls)

• To expand and seal in the borehole (capsel.xls)

• To control expected differential pressure (capsel.xls)

A minimum 3/8” clearance between open hole ID andCAP OD is recommended.

* Contact the nearest TAM office for a complete computer analysis.

CAP Selection Process

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CAP Inflation Process Pressure Chart

1 OPENING PIN pressure to initiate inflation

2 CLOSING PIN pressure to lock packer inflated

A Plug bump pressureB Bleed pressure to check float and shoe for backflowC Pressure up and establish volume marker in displacement tankD Increase pressure slowly to shear OPENING PIN valve to inflateE Stop pumping, pressure declines and stabilizes as packer inflatesF Increase pressure to above CLOSING PIN pressure to lock packer setG Bleed pressure to same level as C to determine inflation volumeH Bleed pressure and verify no backflow, job complete


Use the chart by drawing a horizontal line from thecasing or open hole ID on the right side of the chart tointersect the curve corresponding to selected CAPcasing size (OD). Drawing a vertical line to the bottomof the chart from the intersection of the specific CAP

curve defines the rated working pressure of the CAP.Where anticipated differential pressures exceed therated working pressure, the CAP must be inflated with asolidifying fluid such as cement or operations changedto reduce applied differential.

Differential Pressure Rating

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ProductODB

in. mm

3.06 78

3.50 89

4.00 102

4.38 111

4.63 118

5.13 130

5.56 141

6.06 154

6.56 167

7.50 191

7.69 195

8.06 205

8.06 205

8.75 222

10.25 260

10.88 276

12.75 324

13.75 349

15.25 387

18.50 470

20.63 524

23.00 584

5’ Seal 10’ Seal 20’ Seal

C=5’ (1.5m) C=10’ (3.1m) C=20’ (6.1m)

F=15’(4.6m) F=18’ 6” (5.7m) F=30’ (9.2m)

TAMCAP LONGCAP XTRACAP

TAMCAP = TC full steel reinforced 3 ft. inflation element

XTRACAP = XC partiallyreinforced 5, 10, or 20 ft.inflation element

LONGCAP = LCfull steel reinforced 10 ft. inflation element

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Casing Size

CasingODA

in. mm

1.90 48

2.38 60

2.88 73

3.50(1) 89

3.50 89

4.00 102

4.50 114

5.00 127

5.50 140

5.50(2) 140

6.63 168

6.63(2) 168

7.00 178

7.63 194

8.63 219

9.63 244

10.75 273

11.75 298

13.38 340

16.00 406

18.63 473

20.00 508

(1)Ultra Slim (2)Dual Layer

Partially Reinforced XTRACAP


Inflation ToolThe TAM Inflation Tool is similar to the TAM ComboTool. The Inflation Tool uses self-energizing sealspositioned inside a slightly restrictive polished borerather than seal cups inside the casing ID. This toolsystem facilitates all applications where cement orother solidifying fluids are required for inflation of theCAP. A pressure actuated sleeve between sealsassures that cement remaining inside the work stringis not lost to the wellbore as the tool is pulled upholeto inflate additional Casing Annulus Packers.

The Inflation Tool’s special cement wiper plug allowsplacement of multiple slugs of cement and exact dis-placement control of inflating fluids. Like the ComboTool, the same spring-loaded dogs enable depth controlaccuracy when used in conjunction with a Locator Subor for manipulation of a Port Collar for stage cementing.

CAP Inflation Tools

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Combination Tool

Inflation Tool

Port Collar


Combination ToolThe TAM Combo Tool features dual opposing sealcups for sealing with the casing ID and spring-loadeddogs to accurately land in a Locator Sub or operate a Port Collar. The Combo Tool contains an internalbypass from above to below the seal cups for ease ofrunning in and out of the well. The Combo Tool caninflate multiple CAP with mud or water and be run asa part of the inner string for “One Trip” completionmethods. To achieve circulation through the ComboTool, a ball or wiper plug is placed on a seat below the tool. A special design Combo Tool with premiumtubing threads is available, providing higher tensileand torque strength.

The Combo Tool seal cups seal efficientlyinside API casings. Internal polished

bores or restrictions are not requiredin the casing/tubing string.

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Locator Sub

Choke Sub


AccessoriesLocator SubLocator Subs provide exactdepth control required forlocating and inflating multipleCAP. The profile in the fullbore inside diameter of theLocator Sub is the same as inthe Port Collar. Locator Subscan be run in multiples and inconjunction with Port Collars.The spring-loaded dogs of theCombo Tool or Inflation Toollatch into the recessed profileproviding exact positioning ofthe tool. Applying overpull orslack off assures that the infla-tion tool is properly positioned.

Choke SubThe Premium Threaded ChokeSub is run with the TAMPremium Combo Tool to stopfluid movement below theCombo Tool.

Once a setting ball is pumpedto seat in the Choke Sub, circulation through the tool is stopped, allowing fluid to be directed through theinflation/cementing ports onthe Combo Tool.

A secondary seat allows a largerball to be used in additionaloperations or in case of prema-ture shearing of the primaryball seat.

Port CollarPort Collars offer several unique advantages over conventional stage tools. The full bore Port Collareliminates the need to “drill out” once the cement isplaced. They can be openedand closed multiple timesand pressure tested onclosure. For corrosive envi-ronments and critical casingstrings the Port Collar is availablewith metal-to-metal seals.

Rotational type Port Collars(Left hand torqueto open - Righthand torque toclose) are available forcasing sizes 9 5/8” and larger.All other sizes use a slidingsleeve that is opened and closed byapplying up and down mechanical forces.

The recessed locator profile in the PortCollar is the same as in Locator Subs andfull bore for the pipe weight selected, allowing use of thesame Combo Tool or Inflation Tool for CAP inflation andstage cementing. This “One Trip” completion systemwas developed by TAM in 1990 and has been used inhundreds of horizontal completions.

RecessedLocatingProfile forCombo orInflation Tool

Rotational TypePort Collar

Metal-to-Metal SealsAvailable

Sliding Sleeve Port Collar2 3/8” thru 16”

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Hydraulic Release with Inner String ConnectionA modified version of the TAMHydraulic Release developed in1984 for coiled tubing operationsprovides a mechanism for runningliners without a conventionalliner hanger. The TAM HydraulicRelease allows circulationthrough the end of the slottedliner or screen and rotating andreciprocating the liner while run-ning into the well. The HydraulicRelease disconnects the liner fromthe running string at the bottom ofthe well. While pulling the innerstring and Packer Inflation tool uphole, CAP can be inflated and PortCollars can be operated to cementspecific sections of the liner. All ofthese operations and features arestandard with the TAM “One Trip” horizontal well completion system.

Wiper DartsA unique design of cement wipers and landing dartswith near 100% displacement efficiency allows the use of a multiplicity of darts. The TAM wiper systempumps through drill pipe, tubing, coiled tubing, inflation tools or any combination of these tubulars.

The landing dart’s proven seal technology provides a bubble-tight seal once the system lands below theinflation tool. A special shearable collet design provides a means to expel the dart and then pumpadditional darts for continued operations.

Dart CatcherThe Dart Catcher is used in conjunction with thePremium Combo Tool to allow the use of Wiper Dartsfor accurate fluid placement when cement inflatingCAP, and/or performing cement operations through aPort Collar.

It has an integral landing profile for the Wiper Dart to land and latch into that provides a positive indicationof when the Wiper Dart lands. Additional pressureshears the Wiper Dart through the profile allowingcement to be pumped around the dart via by-passports in the Dart Catcher.

Accessories

Seal

Wipers

Shear Pins

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Annular Fluid Migration Control Using CAPThe migration of annular fluids during the cement curing process can leave voids and flow paths in thecement column thus creating interzone communicationand even flow of fluids to the surface. Numerous

chemical solutions have been developed to combatthis problem. The addition of a mechanical seal(CAP) greatly enhances the success rate of stoppingfluid migration.

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Without a CAPBased on an SPE paper (0149-2136/0081-1206) shown graphi-cally, annular pressure at or near a permeable formation maydecline after displacement due to partial cement gel strengthdevelopment and/or fluid loss from the slurry. If such annularpressure declines to or below the formation pressure, fluidflow from the formation can occur. If such flow continues, per-manent flow channels are left in the annular cement thusallowing long term migration of formation fluids.

With a CAPBy inflating a CAP immediately after bumping the wiperplug, and thus providing full hydrostatic support, annularpressure decline is rapid but the annular pressureachieves equilibrium with the formation pressure beforegel strength develops in the cement and thus no longterm flow can occur nor permanent flow channels left inthe cured cement column.

CBL Log

CBL Log


Casing Annulus Packer Applications - Vertical

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Problem: Completion requires 2nd stage cementing.

Solution: Run HATCH packerPerform 1st stagecement.Bump plug andinflate CAP. Operate Port Collar.Perform 2nd stagecement job.

Problem: Isolate productionzone without primary cement.

Solution: Run straddle CAPto above and belowproduction zone. Set packer.Perforate pipe &formation.

Problem: Annular gas migration.

Solution: Run CAP above gas zone.Perform cement job.Bump plug.Inflate CAP.

TAM-C-TAMCAP:406 2/5/08 3:04 PM

.

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Casing Annulus Packer Applications - Vertical

Problem: Selective completion required forproduction testing.

Solution: Run CAP and cement inflate.

Operate PC for testingand stimulation.

Problem: Open hole bridge plug required to shut off water.

Solution: Run CAP with Plug-Retainer Kit.

Inflate CAP and release work string.

Spot cement on top of plug.


Casing Annulus Packer Applications - Horizontal

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Problem: Horizontal well producing water incenter of lateral.

Solution: Run scab liner with CAP.

Blank pipe to straddle water zone.

Problem: Open hole bridge plug required toshut off water.

Solution: Run CAP with Plug-Retainer Kit.

Inflate CAP.

Release work string.

Spot cement on top of plug.


As Completed As Run

Work String

Casing Shoe

CAP

Locator Sub

CAP(Casing Annulus Packer)

Port Collar

Cement

Production Tubing

Production Packer

Casing Shoe


One Trip Cemented Build Section Completion

A. Run liner with inner string as shown Rotate, reciprocate and circulate as required

B. Circulate ball to choke below inflation toolC. Pressure up to release from linerD. Pick up into Locator SubE. Pressure up to inflate CAPF. Release from Locator Sub and move to next CAP

G. Repeat steps D through F as requiredH. Locate and open Port CollarI. Circulate to condition and cement as requiredJ. Close Port Collar and testK. Pick up to top of liner and reverse excess cementL. Complete well

Guide Shoe

CAP Inflation Tool

Locator SubCAP

Slotted Liner

Inner Tubing StringLocator SubCAP

Bore Insert(Optional PBR)


Inflatable and Swellable Packers

Phone: 1-800-462-7617 1-713-462-7617

Fax: 1-713-462-1536E-mail: [email protected]

Worldwide sales and service contacts available atwww.tamintl.com

Copyright 2011, TAM International Inc. 9/11 Printed in USA

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5.50” VE CAP71/2” OD


65/8” VE CAP8.06” OD

In addition to inflatable Casing Annulus Packersdescribed in this brochure, TAM also provides FluidReactive Expanding Elastomer Casing AnnulusPackers (FREECAP) which expand to provide zoneisolation after contact with wellbore fluids. For specificinformation, refer to the FREECAP brochure.

FREECAPTM

TAM provides a kit that can be adapted to any CAP to convert it to a bridge plug or cement retainer.Uses for this system are shown in application in this brochure. For specific information, contact thenearest TAM office or visit the web site atwww.tamintl.com

PLUG-RETAINER KIT

A special design is available which utilizes a duallayer of slats, thus increasing the differential pressurerating more than 2:1 over standard CAP products.

In excess of one hundred of these Dual Layer CasingAnnulus Packers have been run in horizontal wellsover the last two years with only one packer failure.

Heavy Duty – Dual Layer CAP

Casing Annulus Packers and Accessories

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