compsim.pdf

8/14/2019 compsim.pdf

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COMPLETION PRODUCTSCOMPLETION PRODUCTS

PACKERS

SURSUFACE

FLOW CONTROL

SYSTEMS

SUBSURFACE

SAFETY VALVES


2/40

For more information on Halliburton Products and Servicesvisit our Home page at http:/ / www.Halliburton.com

TOOL DEMO

TOOL DEMO

LITERATURE

LITERATURE

LITERATURE

LITERATURE

INTRODUCTIONSIMULATOR LITE




AHR HYDRAULIC

SET PACKER

TOOL DEMO

HYDRAULIC

PERMA-LACH

PACKER

HYDRAULIC

PERMA-LACH

PACKER

AHR HYDRAULIC

SET PACKER

RH HYDRAULIC

SET PACKER

RH HYDRAULIC

SET PACKER

HYDRAULIC

PERMA-SERIES

HYDRAULIC

PERMA-SERIES

TOOL DEMO

TOOL DEMO

INTRODUCTIONMORE
http://cybertls/phl/demo.avihttp://cybertls/ahr/demo.avihttp://cybertls/ahr.exehttp://cybertls/ahr.exehttp://cybertls/phl.exehttp://cybertls/phl.exehttp://cybertls/rhpkr.exehttp://cybertls/rhpkr.exehttp://cybertls/Mhr.exehttp://cybertls/Mhr.exehttp://cybertls/phl/demo.avihttp://cybertls/MHR/demo.avihttp://cybertls/RHPKR/demo.avihttp://cybertls/Mhr.exehttp://cybertls/MHR/demo.avihttp://cybertls/RHPKR/demo.avihttp://cybertls/rhpkr.exehttp://cybertls/ahr.exehttp://cybertls/phl.exehttp://cybertls/ahr/demo.avihttp://cybertls/phl/demo.avi


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WIRELINE

PERMA-SERIES

TOOL DEMO

HYDRAULIC

VERSA-TRIEVEPACKER

HYDRAULIC

VERSA-TRIEVEPACKER

WIRELINE

PERMA-SERIES

NON MANDREL MOVEMENTHYD PERMA-SERIES

NON MANDREL MOVEMENT

HYD PERMA-SERIES

TOOL DEMOLITERATURE INTRODUCTIONSIMULATOR LITE

TOOL DEMOLITERATURE INTRODUCTIONSIMULATOR LITE

LITERATURE
http://cybertls/Vhr.exehttp://cybertls/Vhr.exehttp://cybertls/VHR/demo.avihttp://cybertls/BWDPKR/demo.avihttp://cybertls/Bwdpkr.exehttp://cybertls/Bwdpkr.exehttp://cybertls/THBPKR/demo.avihttp://cybertls/Thbpkr.exehttp://cybertls/Thbpkr.exehttp://cybertls/THBPKR/demo.avihttp://cybertls/Thbpkr.exehttp://cybertls/Bwdpkr.exehttp://cybertls/BWDPKR/demo.avihttp://cybertls/Vhr.exehttp://cybertls/VHR/demo.avi


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HALLI BU RTON

Incorporating many features from the field-

proven Perma-Lach design, this hydraulic-set

packer offers high performance at a low cost. For

most sizes, it handles stimulation pressures to

10,000 psi and operating temperatures to 275 F.

There are no hold-down buttons, so theres no

chance for leakage around hold-down button

O-rings. A simple change of packer elastomers

equips the tool for H2S or higher temperature

service. Setting and releasing is a study in

simplicity. Run it in on tubing, drop a ball or

set a slickline plug and apply pressure to set the

packer. No tubing manipulation is required. To

release, just pull straight up on production

tubing. The tools small outer diameter speeds

running in. Setting pressures can be field

adjusted, allowing multiple packers to be run

and set during a single trip. Further simplifying

operations, tubing can be spaced out before the

packer is set. With its low cost, simple operation

and dependable performance, the hydraulic-set

Perma-Lach packer will be a field favorite.

Saves when you buy it.

Saves when you run it.Saves when you retrieve it.The hydraulic-setPerma-Lach packer.

HYDRAULIC-SETPERMA-LACH PACKER

ReleaseMechanismProven Perma-Lach

release mechanism.

Secure Hold

Case-carburized slipsbite into casing to pre-

vent slippage in either

direction. Consistent

hardness across tooth

section assures a reli-

able grip even after

multiple sets.

SettingPressuresSetting pressures can

be field adjusted.

AdjustableShear ReleaseEasy to adjust shear

release values to your

completion requirements.

Positive SealThe outside elements

in the triple-seal, multi-

durometer element

package seal off high

pressures while the

softer inner element

molds itself against

casing irregularities for

leak-proof performance.

CN02524

Testing And TreatingSingle And Multiple Zone Production


5/40

The hydraulic-set Perma-Lach packer is versatile

when it comes to completion designs. The field

adjustable shear values for setting and releasing

mean compatibility with a wide variety of

equipment and completion procedures.

This packer can be used as the lower packer in

dual completions.

For single string completions, an on-off tool

allows the packer to act as a bridge plug for

greater safety during tubing changeout.

In multi-zone completions requiring a one-trip

solution, the adjustable setting and releasingshear values make it simple to set the Perma-

Lach packers in a predetermined sequence.

Hydraulic-Set Perma-Lach PackerSingle String

Multi-Zone

Single String

Injection/Production

Dual String Multi-Zone

Completion

The most important feature of the Hydraulic-Set Perma-Lach packer - the Halliburtonspecialist who can help you get full value from the tools high-performance features.

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.

CPP5639. Printed in U.S.A. 1995 Halliburton Energy Services

TUBINGSIZE

in. (mm)

2.375 (60.33)

2.375 (60.33)

2.375 (60.33)

2.875 (73.03)

3.500 (88.90)

2.875 (73.03)

3.500 (88.90)

2.875 (73.03)

3.500 (88.90)

3.500 (88.90)

4.500 (114.30)

3.500 (88.90)

4.500 (114.30)

PACKEROD

in. (mm)

3.786 (96.16)

4.700 (119.38)

4.500 (114.30)

5.980 (151.89)/6.000 (152.40)

5.980 (151.89)

5.820 (147.83)

5.820 (147.83)

6.468 (164.29)

6.468 (164.29)

8.452 (214.68)

8.452 (214.68)

8.233 (209.12)

8.233 (209.12)

CASINGWEIGHT

lb./ft

9.5 - 13.5

13 - 17

17 - 23

23 - 29

29 - 36

29.7 - 39

40 -47

47 - 53.5

CASINGSIZE

in. (mm)

4.500 (114.30)

5.500 (139.70)

7.000 (177.80)

7.625 (193.68)

9.625 (244.48)

CN02521

CN02522

CN02523


6/40

Hydraulic-Set AHC Retrievable Packers

AHCHydraulic-Set Packer

HALLIBURTON

Halliburtons new Hydraulic Set AHC Packer offersoutstanding performance, reliability, and versatility.With this packer you get the performance and reliabilityof a permanent packer without the time-consuming andcostly milling operations normally required to retrievea permanent packer.

Reliability and Versatility

The AHCs large inside diameter makes this packerideal for a wide variety of completion applications.

This unique design can be easily configured for mono-bore completions or into compact multi-bore designscapable of handling dual completions, electric cable,control line and instrument line feedthroughs. Evenwhen configured for multi-bores, the sealing duties arehandled by a reliable high performance concentricelement package used in single bore applications. Nomandrel movement during setting means that multipleAHC packers can be run together in a completion andset simultaneously or selectively.

The packers reliability is enhanced by having fewelastomeric seals. The seals that are used are proven,

performance tested and positioned to optimize protec-tion of the well.

Retrieving Options - Straight-Shear,Chemical-Cut or Quick-Mill

The release options can be tailored to the completion

requirements. If your completion requires a straight

shear release packer, the adjustable Shear Release ring

is used. For high pressures or high load capabilities, the

adjustable Shear Release ring is replaced with a lock

ring and the packer is released by chemically cutting the

packer mandrel, then retrieving the packer with straight

pull on the tubing. No components or metal cuttingsare left in the well. In the event the packer must be

milled, the slip is located at the top of the packer

providing a very short milling distance to release.

This Large Bore Retrievable Packer Combines Permanent Packer Performance with

Multiple Retrieval Options for a Total Completion Solution

The Barrel Slip Provides High LoadCapability Without DamagingCasing

Proven, Highly Reliable,Three-Piece, Multi-DurometerElement Package To Suit MediumTo High Pressure And TemperatureEnvironments

Setting Piston BelowThe Elements

Adjustable Shear Release

U.S. Pat. No. 5,117,906CN03186

Adjustable Start-To-SetPressure

Can Be Configured withRatch-LatchHead Or PremiumTubing Thread

Single-Piece Mandrel EliminatesThe Need For O-Ring Seals AboveThe Elements


7/40

H00657 9/97 1997 Halliburton Energy Services, Inc. All Rights Reserved Printed in U.S.A.

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.

Visit our website at www.halliburton.com

Releasing Procedures

Straight ShearReleasing-The AHC packer isreleased by straightpull on the produc-tion tubing.

Chemical CutReleasing-The AHC packer isreleased by chemi-cally cutting thepacker mandrel in apredetermined loca-tion. This releasesthe packer so that

the productiontubing, packer, andtailpipe are pulledintact.

Quick-Mill Release-The AHC packer can be retrieved by milling only the externalslip which is located at the top of the packer.

CN03888

CN03889

CN03890

CN03206

CN03188

The reliability, versatility, performance, and ease of service of the AHC packer makes it a prime candidate for con-

siedration in your completion needs. Contact your Halliburton representative - your Solution ConnectionSM.

Casing Size Casing Weight Packer OD Packer ID4 1/2 9.5-11.6 3.83 1.885

5 1/2 13-17 4.72 2.990

7 23-26 6.10 3.950

29-32 5.95 3.880

7 5/8 29-39 6.44 3.880

9 5/8 40-47 8.47 4.95

47-53 8.30 4.875

No mandrelmovement

makes the AHCwell suited formulti-packercompletions

Large I.D.for big

bore/mono-borecompletions

Unique single piecemandrel allows multi-bore capabilities for

dual bores, cable feedthrough, control lines,and instrument lines


8/40

Single Retrievable Completions

HALLIBURTON

Save valuable rig time

with Halliburtonsreliable RH packer

Many operators have saved a tremendous

amount of rig time with Halliburtons proven RH

packer a hydraulic-set system easily converted

to selective set so the same packer can be used

for single or multizone wells. It has safe,

low-pressure setting requirements, but setting

pressures can be easily varied in the field. In anycase, the tree can be set and flanged up before

setting as the packer does not require mandrel

movement to set. A lower set of mechanical slips

retains the packer against downward forces and

an upper set of pressure-actuated button slips

retains the packer in position against differential

pressure from below. The more the differential

pressure increases below the packer, the harder

the Hold-down buttons bite into the casing.

And when its time to release, no tubing rotation

is required a simple, straight upward pull on

the tubing is all thats needed. Fast, simple,

straightforward it all adds up to one reliable,

time-saving packer.

RHPACKER

PositiveSealingTriple-seal multidurometer

element package contains

two high durometer end ele-

ments. The middle element

is softer to seal against cas-

ing irregularities and low

pressures. End elements

have molded, self-retracting

springs.

ReliableDurable tungsten-car-bide disc inserts inthe Hold-down but-

tons are protectedfrom the casing wallas the packer is low-ered into the well.

Sure HoldReliable casing bitein all grades including P110 and

harder is providedwith case-carburizedslips. Contouredslips are designed tomatch the casing IDwithout belling.Easier packerrelease stems fromthe unique dovetailslip design.

HN00012


9/40

CPP5616 1994 Halliburton Energy Services Printed in U.S.A.

Halliburtons RH packer is the standard with a proven performance record. Let yourHalliburton representative show you how an RH packer can help you save rig time.


Setting and Releasing Operations

The RH packer is designed to be set by pressuring

up the tubing string against a plugging device

below the packer. The RH packer has proven to

be one of the industrys most reliable,

retrievable packers.

Schematic 1:

Running In

Schematic 2:

Setting

Schematic 3:

Releasing

Schematic 4:

Selective

Setting

Schematic 1: Running In A heavy duty guide at the lower

end of the packer serves as a gage ring.

Schematic 2: Setting After sealing the tubing by either

dropping a sealing ball or landing a plug in a nipple by wireline,

pressure applied through the tubing initiates the setting.

Schematic 3: Releasing After pressure differential across

the packer is equalized, a straight upward pull on the tubing

string shears the pins designed to release the packer. Large

bypass areas in the RH packer aids in retrieving. Sealing ele-

ments reduce binding or swabbing problems.

Schematic 4: Selective setting A selective setting adapter

assembly is available, allowing any number of packers to be

used in a single string. The adapter uses a sleeve and knock-out

plug to seal off the pressure setting chamber of the packer.

Packers are retrieved in the usual manner.

RH PackerCASING CASING PACKER PACKER

SIZE WEIGHT OD ID

IN (mm) LB/FT IN (mm) IN (mm)

3.75 (95,25) 1.62 (41,15)

3.83 (97,28) 1.92 (48,77)

3.65 (92,71) 1.53 (38,86)

4.31 (109,47) 1.94 (49,28)

4.06 (103,12) 1.53 (38,86)

4.12 (104,65) 1.94 (49,28)

3.91 (99,31) 1.91 (48,51)

4.62 (117,35) 1.94 (49,28)

4.50 (114,30) 1.94 (49,28)

5.00 (127,00) 1.92 (48,77)

5.73 (145,54) 2.78 (70,61)

5.50 (139,70) 2.38 (60,45)

6.19 (157,23) 2.38 (60,45)

6.12 (155,45) 2.37 (60,20)

6.00 (152,40) 2.89 (73,41)

5.88 (149,35) 2.38 (60,45)

6.00 (152,40) 2.78 (70,61)

5.88 (149,35) 2.88 (73,15)

5.77 (146,56) 2.38 (60,45)

5.50 (139,70) 2.38 (60,45)

6.64 (168,66) 2.91 (73,91)

6.40 (162,56) 2.89 (73,41)

7.74 (196,60) 2.78 (70,61)

7.55 (191,77) 2.90 (73,66)

8.62 (218,95) 3.00 (76,20)

8.38 (212,85) 2.34 (59,44)

8.38 (212,85) 3.00 (76,20)

8.38 (212,85) 4.73 (120,14)

8.31 (211,07) 2.34 (59,44)

8.31 (211,07) 3.00 (76,20)

8.31 (211,07) 4.73 (120,14)

9.66 (245,36) 4.73 (120,14)

9.44 (239,78) 4.73 (120,14)

12.10 (307,34) 5.00 (127,00)

9.5 - 13.5

10.5 - 11.6

11.6 - 15.1

11.5 - 13

15 - 18

18 - 23

13 - 17

17 - 23

20 - 26

17 - 24

24 - 32

17 - 23

20 - 26

23 - 26

23 - 29

29 - 32

29 - 35

38 - 40

24 - 29.7

29.7 - 39

24 - 32

32 - 40

36 - 40

40 - 47

47 - 53.5

40.5 - 45.5

51 - 60.7

61 - 72

4.500 (114.30)

5.000 (127,00)

5.500 (139,70)

6.000 (152,40)

6.625 (168,28)

7.000 (177,80)

7.625 (193,68)

8.625 (219,08)

9.625 (244,48)

10.750 (273,05)

13.375 (339,73)


10/40

Permanent HP/HT CompletionsFracPac and Sand Control ServicesHighly-deviated and Horizontal Completions

When rig time is a premium,

the single-trip Hydraulic-Set,Perma-Series packer offersproven performance andeconomy

The Hydraulic-Set Perma-Series packer is a per-

manent drillable production packer that is the single-

trip version of the proven Perma-Series packer

equipped with a Ratch-Latch head. It is fast becoming

a field favorite for highly deviated and/or single tripproduction and injection applications. It is especially

well suited for offshore completions where economics

require a single-trip packer.

Leading-edge design features include a one-piece

mandrel and seal bore that eliminates a potential leak

path. Also, the low profile means greater running

clearances to help reduce problems that may occur

when running in highly deviated and horizontal

wells. All premium, metal-to-metal thread connec-

tions add to the dependability of the packer.

Important cost savings are built into the design of

the Hydraulic-Set Perma-Series packer, especially

when well conditions require exotic materials for

the mandrel. A special short head version of the

packer means less exotic material is needed and

that reduces the cost.

HYDRAULIC-SETPERMA-SERIES PACKERS

HN00205

Ratch-LatchSealbore with SealAnchorprovides high tensile strengthand large bore throughpacker and seals.

One Piece Mandreland Sealboreeliminates a potentialleak path.

Metal-To-MetalBackup Shoesoffer a 360casing wallcontact that preventsseal element extrusion.

Case-CarburizedSlipsprovide maximum casingcontact with uniform slippenetration.

Bottom Sub andPiston Housingmade of a single piece,eliminating a potentialO-ring leak path.

Setting PistonO-Ringsstandard design consistsof two Aflas O-rings withPEEK backups, andtwo Viton O-rings withPEEK backups. Thiscombination providesthe downhole conditionresistance of the Aflassealing compound withthe cold temperaturesurface testing integrityof the Viton compound.

Metal-To-Metalpremium thread connec-tions on the packer, sealanchor and Ratch-Latchassembly.

Triple Seal

MultidurometerElement Packageis a geometric design toseal effectively at highor low temperatures orpressures; available in325F, 400F and 450Ftemperature ratings.

HALLI BU RTON


11/40

CPP5619 1995 Halliburton Energy Services Printed in U.S.A.


The Hydraulic-Set Perma-Series packer has

proven to be very easy to use in flanged-up

completions common in offshore operations.

It sets with low pressure, all components are

rotationally locked, and materials are suitable

for milling. No tubing manipulation is

required to set the packer and the Hydraulic-

Set Perma-Series packer is compatible with

standard Halliburton accessory equipment.

CASING SIZE CASING WEIGHT PACKER OD PACKER SEALING BORE

PACKER AND SEAL PACKER AND SEAL

UPPER SEAL BORE ASSEMBLY MINIMUM ID* LOWER SEAL BORE ASSEMBLY MINIMUM ID*

5.000 15-21 3.96 3.12 1.91

5.500 13-20 4.54 3.5 2.36 2.375 1.735

20-23 4.45 3.5 2.36 2.375 1.735

6.625 17-32 5.468 4.25 3.17 3.25 2.35

17-20 5.875 5 3.875 4 2.875

7.000 17-23 6.18 4.25 3.17 3.25 2.35

17-20 6.25 5 3.875 4 2.875

23-32 5.875 4.25 3.17 3.25 2.35

23-38 5.687 4.25 3.17 3.25 2.35

32-44 5.468 4.25 3.17 3.25 2.35

7.625 26.4-39 6.375 5 3.875 4 2.875

33.7-45.3 6.25 5 3.875 4 2.875

33.7-47.1 6.18 4.25 3.17 3.25 2.35

9.625 36-59.4 8.125 6.5 4.85 5 3.875

40-47 8.42 7 6 6 4.85

53.5 8.31 7.25 6.023 6 4.85

10.750 55.5-60.7 9.28 7 6 6 4.85

* minimum IDs may vary depending on tubing thread connection

Hydraulic-Set Perma-Series Packer

Other sizes available on request.

Lower Seal Bore (short)Ratch-Latch Head

(Most Economical Design)

Upper Seal BoreRatch-Latch Head

(Largest Bore)

Metal-To-MetalBack-Off Sub Head

(optional relatchcapability shown)

HN00206


12/40

PermanentPermanent HP/HTHorizontal Completions

A variety of options inone high-performanceproduction packer the

Perma-Series

packer

Single or multiple zone completions are

served by one of the most advanced perma-

nent packers available in the industry the

Perma-Series packers. Electric-wireline set or

hydraulic-set on the workstring, this tool

leaves the packer bore free of all setting

devices and provides a large production con-

duit through the packer. The packers

contoured C-slip design provides maximum

casing contact with uniform slip engagement.

Case carburized slips also provide controlled

hardness depth and maximum hardness

across the tooth section. Should milling

become necessary, upper packer components

are locked and made of millable materials

for fast removal, saving rig time.

PERMA-SERIES PACKERS

FlexibleMultiple receiving heads

and bottom sub arrange-

ments provide the flexibili-

ty to adapt the Perma-

Series packer to your par-

ticular completion needs.

ReliableHigh or low temperatures,

high or low pressures, the

triple-seal multidurometer

element package provides

an effective seal. Themetal-to-metal backup

shoes provide full 360o

casing wall contact. The

unique design helps com-

pensate for casing

irregularities, preventing

seal element extrusion.HP/HTCapableA fully engineered HP/HT

element system is available

for applications of up to

15,000 psi differential

pressure at 450oF.

DependableSmall running O.D. and

internal C-ring slip help

prevent upward movement

of wedge and a unique

C-ring external slip design

provides added resistance

to presets.

OptionalReceivingHeadArrangements

Lug-Style

receiving

head for

verticalwells

Lug-Style

receiving

head with

scoop guidefor deviated

wells

Ratch-Latch

receiving

head for high

tensilestrength or

maximum

flow capability

Optional BottomSub Arrangements

Plain bottom

sub for sump

packer

applications

Sealbore

extension

thread for

additional seal

surface

Tubing or

millout

extension

thread for

tailpipe

accessories

HALLIBURTON

CN01682

CN01683

C N 0 1 6 8 4

C

N01685


13/40


14/40

Deviated or horizontal completionsTubing conveyed perforating (TCP)Stimulation and FracPacsm service

Single-Trip RetrievablePacker for HighAngle/TCP/Stimulation

Completions

The Hydraulic-Set Versa-Trieve packers unique

anti-preset mechanism system helps eliminate

the problems that can be encountered when run-

ning a packer in horizontal and highly deviated

wells. The hydraulic setting piston is isolated

from unexpected load forces that may accidently

set the packer.

The Hydraulic-Set Versa-Trieve packer brings

real value to conventional wells too. The single-

trip capabilities of this packer make it ideal for

use with Halliburtons VannSystem tubing-con-

veyed perforating guns. And, since the packer is

mechanically held in the set position, it is ideally

suited for stimulation operations where tubing

contraction and mechanical shock loads may

release a straight pull-to-release packer.

More trouble-free running in, positive setting and

holding, and fast, dependable retrieving mean

the Hydraulic-Set Versa-Trieve can really help

lower overall costs for highly deviated

or horizontal well completions or completions

involving tubing conveyed perforating andstimulation operations.

HYDRAULIC-SETVERSA-TRIEVE PACKER

DependableSetting andRetrievingBi-directional case-car-burized slips hold against

pressure from above andbelow in all casing grades.The slips are locatedbeneath the packer ele-ments, away from debris,simplifying releasingand retrieval. If, for somereason, milling is required,critical external compo-nents are rotationallylocked.

Move this packeruntil its in theright place!Anti-preset mechanism

helps ensure that the

packer does not set until

the setting piston moves.

No tubing rotation is nec-

essary during setting or

retrieving.

Designs availableto meet allenvironments.Triple-seal, multidurome-ter packer element sealsagainst high and lowpressure and againstcasing irregularities.Metallurgy of standardpacker is for H2S ser-

vice. Exotic metals andelastomers are available.

HN00413

Seal AnchorThreaded andPinned to PreventBackoff

Protected C-RingRelease Mechanism

Anti-Rotation LugLocks ExteriorComponents toFacilitate Milling

HALLIBURTON

HN002

03


15/40

CASING CASING PACKER PACKER

SIZE WEIGHT OD ID

(in) (mm) (lb/ ft) (in) (mm) (in) (mm)

14-17 4.87 118.62

20-23 4.50 114.30

3.250 82.55

3.880 98.55

3.250 82.55

3.880 98.55

26-32 5.92 150.68 3.250 82.55

32-38 5.77 146.56 3.000 76.20

3.250 82.55

3.880 98.55

3.250 82.55

3.880 98.55

3.250 82.55

3.880 98.55

3.250 82.553.880 98.55

3.880 98.55

5.000 127.00

3.880 98.55

5.000 127.00

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 sa

Hydraulic Set Versa-Trieve Packer

Other sizes available on request.Production seal assembly ID typically compatible with tubing that has comparable ID to packer bore.

7.000 177.80

7.825 193.68

7.750 196.85

9.625 244.48

5.500 139.70

17-23 6.19 156.72

23-29 6.00 152.72

24-29.7 6.68 169.67

29.7-39 6.44 163.58

42.8 6.19 156.72

46.1-48.6 6.17 156.72

36-43.5 8.52 216.41

43.5-53.5 8.30 210.82

2.750 69.85

Running Set

Retrieving

Tool

Triple Seal Bi-Directional

Multidurometer Case-Carburized

Element Package Slips

HN00411

H

N00412

HN00410

HN00409


16/40

Features and Benefits upper internal slip design retains

the setting force throughout thepacker assembly; lower internalslips prevent upward movementof the upper wedge whilerunning

internal locking-slip ring aids infast removal, saving rig time ifmilling becomes necessary

triple-seal multidurometer sealelement package effective athigh or low temperatures andpressures

metal-to-metal backup shoes with360 casing wall contact preventseal element extrusion and offerreliable sealing under ultrahighpressures

contoured C-slip design providesmaximum casing contact withuniform slip engagement

case carburized slips providecontrolled hardness depth andmaximum hardness across tooth

section core of slip retains originalmetallic structure for easy milling

maintains a large fluid bypassarea through the packer

saves rig time provides flexibility with multiple

receiving head and bottom suboptions

can be adapted forhigh-pressure/high-temperatureapplications

Production packers for single or multizone completions.

Wireline-Set Perma-SeriesPackers

H A L L I B U RTO N

Halliburtons Wireline-SetPerma-Series packers areeffective, differentialproduction packers forsingle or multizonecompletions. Thesepermanent packers may

be electric-wireline orhydraulically set on theworkstring. They are alsodesigned to leave the packer

bore free of all settingdevices and maintain alarge fluid bypass areathrough the packer.Operating envelopes are agraphical representation ofthe safe combination ofdifferential pressure andapplied tubing loads andare available for most

Perma-Series packers.

Applications

high formation, unloadingdifferential, or stimulationpressure areas

pulling tubing withoutunseating packers

high bottomhole temperatures downhole conditions demand

special running clearance twin-flow chemical injections

systems

Special Shear

A rr an ge m e n t

Receiving Head

Upper Internal

Sl i p s

C ase - C ar b u r i ze d

Upper Slips

Lo wer Internal

Sl i p s

Tr i p l e - Se alM u l t i d u r o m e t e r

El e m e n t s

Metal Back- U p

Sh o e s

C ase - C ar b u r i ze d

Lo wer Slips

P e r m a - S e r i e s

Wireline-Set Packer


17/40

SUPERIOR

PERFORMANCE

SUPERIOR

PERFORMANCE


TOOL DEMO

LITERATURE

LITERATURE SIMULATOR LITE

SIMULATOR LITETOOL DEMO

WELLSTAR

WELLSTAR
http://cybertls/spvalve/demo.avihttp://cybertls/spvalve.exehttp://cybertls/wellstar.exehttp://cybertls/WELLSTAR/demo.avihttp://cybertls/spvalve.exehttp://cybertls/spvalve/demo.avihttp://cybertls/wellstar.exehttp://cybertls/WELLSTAR/demo.avi


18/40

CN03155

Spherical sealingflapper providingunsurpassed MTM sealing

Patented Design Recognized by Petroleum Engineering International for Engineering Innovation.

HALLIBURTON

The Worlds Most Reliable Safety ValveSetting Tomorrows Standards In Reliability

Tubing Retrievable Subsurface Safety Valve

CN03162

Ultimate Design Solution

For Reliability Unsurpassed Performance

Full Metal-to-Metal WellContainment


19/40

SP TM Reliability Features

SP The Ultimate Design Solutionfor Reliability

CN03163

The reliability of the Halliburton SP

Non-Elastomer Rod Piston TRSVstarts with design that is confirmedthrough industry leading verificationand is seen through industry leadingperformance.

Sole emphasis is placed on minimiz-ing life cycle costs as opposed tominimizing equipment build cost.The SP Non-Elastomer Rod PistonTRSV represents a comprehensivedesign solution for reliability.

Design reliability analysis quicklyillustrates the SP valves attentionto the critical design reliability issues.

Performance based sealing. Enhanced metallurgy for

critical items. Debris isolation/protection Mechanical loading of critical items.

The Halliburton SPTM

Valve provides thesolution to achievingtodays life-of-the-reservoir completiondesigns.

Sealing

100% MTM well containment inclosed position.

Verified metal-to-metal flapper seal. Metal-to-metal flapper seat connection. Flapper passes low pressure nitrogen

leakage verification through 120 slamclosures (API Class II Sand Test consist of7 slam closures).

Each body connection verified to fullcapability combining external/internalpressure, maximum temperature andcompression/tensile loading.

Non-elastomer dynamic seals withmetal-to-metal static seal in the open andclosed position.

The metal-to-metal seal is independentlyverified during the manufacturingprocess without the dynamic seals inplace, ensuring metal-to-metal integritywith every valve made.

Hydraulic system isolated from wellpressure by metal-to-metal seal whenvalve is open.

Enhanced Metallurgy

Upgraded materials for all critical items.Selective metallurgy upgrade can alter

the design reliability by 500% to 1000%in many cases.

Debris/Isolation Protection

Wiper ring on upper flow tube andmetal-to-metal flow tube seating at the

bottom isolate critical components duringwell production.

Upper wiper ring also prevents circula-tion of well fluids through the innerspring chamber during valve closure.

Maximized piston area/closingspring force.

Selective internal exercise profileprovides ability to manipulate flow tube.

Mechanical Loading Concentric thrust bearing eliminates

torsional effects of helical spring andwear of dynamic seals.

Flow tube shock absorber protects flowtube, dynamic seals, rod piston andupper MTM hydraulic seal fromslam closure.

Rigid flow tube concentrically guided atboth ends minimizes piston rod loading.

Increased rod piston size providingincreased durability.


20/40

Halliburtons Metal-To-Metal TechnologyProviding Unsurpassed Reliability

CN03165

Superior Performance

7 Years Without a Single Hydraulic FailureThe Halliburton SP hydraulic actuator system isthe ultimate design solution for overall reliability.This is supported by the fact that the SP Valveestablished the performance standard for hydraulicactuation, with over 1,250 valve years of operationand no failures. Actuator design is consistentthrough all sizes and pressure ranges, providingeasy correlation of performance. The solid top subconstruction provides for virtually unlimitedpressure capability of the hydraulic chamber.The manufacturing process individually confirms

the metal-to-metal sealing of the hydraulic actuatorof each and every valve further ensuring reliability.

Premium Metal-to-Metal Body Connections

Each Halliburton body joint design is verified to thefull working envelope using the Halliburton DeepWell Simulator. This allows verification of not onlyburst and tension, but also collapse and compression,which others often ignore due to expensive fixturingrequired to conduct this type testing. Halliburtondoes not conduct any same as qualification of TRSVbody connections. Every body joint size and design

goes through the full rigorous verification test.

True Metal-to-Metal Flapper Sealing

True metal-to-metal sealing, provides superiorreliability and durability at the critical stage of valveclosure. Recognized by Petroleum EngineeringInternational for innovative engineering, thepatented spherical sealing flapper design providesunsurpassed metal -t o-metal seali ng.

The flapper seat is coupled to the valve body byutilizing a torqued metal-to-metal seal. Thiseliminates cyclic seal loading experienced by other

comparative designs. Each new design is thoroughlytested including a tortuous slam closure testexceedi ng API 14A Class 1 and 2 by nearl y 20 fold.

Upper MTMHydraulic Seal

Non-ElastomerDynamic Seals

Lower MTMHydraulic Seal

PETR

OL

EUM

E NG I N

E E R INTE

RN

AT

IO

NA

L

S P EC I A L

MERITORIOUS

AWARDFOR

ENGINEERI

NGINNOVATIO

N


21/40

CN03762

H00104 5/97 1997 Halliburton Energy Services, Inc. Printed in U.S.A

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.

Halliburton Deep Well Simulator

The Halliburton Deep Well Simulator allowsequipment to be tested under simulated wellconditions. This advanced system is used

extensively by Halliburton to test equipmentintended for hot, high pressure, hightemperature gas or fluid environment whilesimultaneously applying tension orcompression loads or dynamic manipulation.Tests have been successfully conducted insimulated conditions up to 400 degreesFahrenheit, 20,000 psi hydrostatic pressureand more than 400,000 lbs compression and600,000 lbs tension.

Use of this simulator allows Halliburton toaccelerate development of new equipmentdesigns and sealing technology to provide

answers to the increasing demands of todaysindustry.

Rigorous Testing Program

Each SP TRSV design undergoes extensivetesting well beyond the industry guidelinesestablished by API 14A, including as aminimum the following: API 14A functional test API 14A Class 1 and 2 verification testing

at Halliburton API facility API 14A Class 1 and 2 third party

verification testing and certification Combined pressure (full external and

internal) and temperature (maximumrated and ambient) tests undercompression and tension loads.

Differential opening and slamclosure testing

Extensive sand closure testing usingNorth Sea endurance testing standards,e.g. higher flow rates and increasednumber of cycles, 120 closures at higherflow rates versus only 7 closures as

required in API 14A.

Tool Loading Jack

Load Flange

Heating System AirHandler and Controls

Hot Air Discharge

Hot Air Return

SSSV

Hot Air Flow Path

Power Pack for ToolLoading Jack

Halliburton Deep Well Simulator


22/40

HALLIBURTON

Simple, Compact Design For OptimumReliability And Durability

WellStarTM

Tubing Retrievable Subsurface Safety Valve

CN02677

CN03155

Spherical sealing

flapper providingunsurpassed MTM sealing

Compact Design andPremium Material

Unique Actuation withSuperior Durability

Full Metal-to-Metal WellContainment


23/40

WellStar Sets the Standardfor cost-effective, dependable TRSV

performance by minimizing long

term maintenance costs, and produc-

tion shutdowns due to valve failure.

WellStar safety valves are the prod-

uct of Halliburtons most recentadvances in valve design technology.

These hydraulic operated, downhole

tubing retrievable safety valves

provide reliability and economy

through a number of design

innovations.

The Simple Compact Design ofthe WellStar provides a reliable

cost-effective safety valve ensuring

trouble free operation. The valve

contains two metal-to-metal bodyconnections with only one connec-

tion being exposed to tubing pres-

sure. The single piece actuator

enhances the valves unique com-

pact design and provides smooth

operation and superior durability.

Premium Material Constructionis provided through enhanced met-

allurgy selection while providing an

economical valve. All components

in the WellStar valve are made froma minimum of 9Cr-1Mo material for

a 9Cr-1Mo valve or a minimum of

13Cr material for any component in

a 13Cr valve. Upgrading of valve

materials was reported by SINTEF

as one of the factors contributing to

reliability improvements seen

between their Phase III and IV

Subsurface Safety Valve Reliability

Reports.*

The Unique Hydraulic Actuationuses a single-piece piston/flow tube

which eliminates seals and connec-

tions. It provides for a smooth oper-

ation and rugged durability during

well production. The critical internal

components of the valve are

exposed only to clean hydraulic

CN02675

*SINTEF Reports STF75F89030 and STF75 F91038, Reliability of Surface Controlled Subsurface Safety Valves-Phase III

and Phase IV, Foundation for Scientific and Industrial Research at the Norwegian Institute of Technology

Lock OpenCommunicationSystem EliminatesConstruction Seals

Hydraulic/SpringChamber NotExposed To WellFluids

Full MTM Flapperand Seat System

fluid, preventing exposure of the

spring and dynamic seal surfaces

to wellbore fluids and debris. The

flapper closure mechanism is fully

protected by the flow tube during

production.

Superior Durability isachieved by maximized opening

and closing forces of the WellStar

safety valve. The enlarged piston

area provides maximum capability

in opening the valve when solids

are present. Likewise the enlarged

piston area (increasing well assist

closure) and the stronger power

spring (typically more than double

other comparative designs) pro-

vides reliability of closure in debrissituations. The piston area and

flapper shut-in area are balanced

to provide flapper protection

against differential opening.

Full Metal-to-Metal WellContainment is achieved provid-ing superior reliability at the criti-

cal stage of valve closure. The

patented, award winning, spheri-

cal sealing flapper design provides

true reliability and unsurpassedmetal-to-metal sealing. The flapper

seat is coupled to the valve body

by utilizing a torqued metal-to-

metal seal. This eliminates cyclic

seal loading experienced by other

comparative designs. Each new

design is thoroughly tested includ-

ing a tortous slam closure test

exceeding API 14A Class 1 and 2

by nearly 20 fold. Each metal-to-

metal WellStar body connection is

verified for durability through

combined load verification testing

with full external/internal pres-

sure, maximum temperature and

compressive/tensile loading.


24/40

Halliburton WellStarTM Tubing Retrievable Safety Valve

Design Innovations

Feature WellStar Other Comparative TRSVSealing

100% MTM Well Containment InClosed Position Yes No

Verified Metal-To-Metal Flapper Seal Yes No

Metal-To-Metal Flapper Seat Connection Yes No

Flapper Seat Design Eliminates Cyclic Yes No

Seal Loading

Number Of Well Containing Body Seals 1 Typically 2 Or More

Flapper Passes Low Pressure NitrogenLeakage Verification Through 120 Slam Yes NoClosures (API Class II Sand Test ConsistOf 7 Slam Closures)

Each Body Connection Verified To FullCapability Combining External/Internal Yes Typically NoPressure, Maximum Temperature AndCompression/Tensile Loading

Debris/Corrosion Protection

Majority Of Internal ComponentsIsolated From Well Fluids And Yes NoExposed To Clean Hydraulic Fluid

Single Piece Piston/Flow Tube(Enhanced Protection Due Yes NoTo Minimized Componentry)

Upper End Of Flow Tube Fully IsolatedFrom Well Debris Yes No

Enlarged Piston Area/MaximizedClosing Spring Force* Yes No

Flapper Mechanism Isolated From

Wellbore By MTM Seating Of The Yes No

Flow Tube Below The Flapper

All Components 9Cr-1Mo Premium Material Policy Or Better For Any Typically Contains

Component In A 9Cr-1Mo Valve Lower Grade Materials

Permanent Lock Open System

No Additional Seals Required ToIncorporate Secondary Communication Yes NoCapability

Single-Trip Operation (Minimizes CostAnd Safety Concerns) Yes No

Surface Verification Throughout Lock

Open Process Yes No

* Size of piston area and spring force has a direct relationship to reliability in debris


25/40

Halliburton WellStarTM Tubing Retrievable Safety Valve

General Specifications

Tubing Maximum Internal Lock Pressure Length

Size OD Packing Bore Profile* Rating

in. in. mm in. mm psi kg/cm2 in. mm

3.63 92 5,000 352

2-3/8 3.70 94 1.875 48 X 5,000 352 47.1 1196

3.97 101 10,000 703

4.59 117 5,000 325

2-7/8 4.65 118 2.313 59 X 5,000 325 51.2 1300

4.91 125 10,000 703

5.09 129 5,000 325

3-1/2 5.20 132 2.813 71 X 5,000 325 56.3 1430

5.62 143 10,000 703

6.62 168 5,000 325

4-1/2 6.73 171 3.813 97 X 5,000 325 63.5 1613

6.97 177 7,500 527

*Genuine Otis X Profile

H00105 1/97 1997 Halliburton Energy Services, Inc. Printed in U.S.A.



Permanent Lock Open SystemThe WellStar valve is designed to be permanently locked open when operating conditions dictate the

necessity. Permanent lock open is achieved using a simplified single-trip operation that minimizes both costsand safety concerns associated with multiple well intervention. The single trip lock open procedure com-

bines mechanical (slickline) and hydraulic operations and offers operational simplicity and surface verifica-tion not found in other lock open systems. The innovative WellStar lock open/communication system elimi-nates potential leak paths which are typically found in other comparative lock open systems.

Rigorous Testing ProgramEach Wellstar TRSV design undergoes extensive testing well beyond the industry guidelines established by

API 14A, including as a minimum the following: API 14A functional test API 14A Class 1 and 2 verification testing at Halliburton API facility

API 14A Class 1 and 2 third party verification testing and certification Combined pressure (full external and internal) and temperature (maximum rated and ambient) tests

under compression and tension loads. Differential opening and slam closure testing Extensive sand closure testing using North Sea endurance testing standards, e.g. higher flow rates and

increased number of cycles, 120 closures at higher flow rates versus only 7 closures as requiredin API 14A.


26/40

TOOL DEMO INTRODUCTION

INTRODUCTION

INTRODUCTION


LITERATURE

LITERATURE

LITERATURE

SIMULATOR LITE

SIMULATOR LITE

SIMULATOR LITE

DURASLEEVE

DURASLEEVE

TOOL DEMO

TOOL DEMO

RPTRPT

MONOLOCKMONOLOCK

TOOL DEMO

MIRAGEMIRAGE

TOOL DEMO INTRODUCTIONLITERATURE SIMULATOR LITETOOL DEMO

INTRODUCTIONMORE
http://cybertls/DURASLEV/demo.avihttp://cybertls/Duraslev.exehttp://cybertls/Monolock.exehttp://cybertls/Rpt.exehttp://cybertls/Duraslev.exehttp://cybertls/Monolock.exehttp://cybertls/Rpt.exehttp://cybertls/DURASLEV/demo.avihttp://cybertls/MONOLOCK/demo.avihttp://cybertls/RPT/demo.avihttp://cybertls/MIRAGE2/demo.avihttp://cybertls/Mirage2.exehttp://cybertls/Mirage2.exehttp://cybertls/MIRAGE2/demo.avihttp://cybertls/Duraslev.exehttp://cybertls/Monolock.exehttp://cybertls/Rpt.exehttp://cybertls/Mirage2.exehttp://cybertls/MIRAGE2/demo.avihttp://cybertls/RPT/demo.avihttp://cybertls/MONOLOCK/demo.avihttp://cybertls/DURASLEV/demo.avi


27/40


SAFETY SETSAFETY SET

TOOL DEMO INTRODUCTIONLITERATURE SIMULATOR LITETOOL DEMO
http://cybertls/SAFETY/demo.avihttp://cybertls/Safety.exehttp://cybertls/Safety.exehttp://cybertls/SAFETY/demo.avihttp://cybertls/SAFETY/demo.avihttp://cybertls/Safety.exe


28/40

Improved Performance With Non-Elastomer Design

DURASLEEVE CIRCULATION/PRODUCTION SLEEVE

HALLIBURTON


29/40

Improved seal material and high pressureequalizing features are major innovations builtinto Halliburton's DURASLEEVE circulation/production sleeve. These improvements set newperformance standards for all sliding sleevedevices in the industry. Halliburton's leading-

edge design andmanufacturing

technology, with over100 years of combinedsleeve designexperience providesthese high-performance features.

The new DURATEFECM seal is a non-elastomer engineeredcomposite material(ECM) available onlyfrom Halliburton.

DURATEF ECM is so advanced that temperatureand pressure ranges for testing have beenexpanded dramatically, resulting in a newspecification for sleeves. During testing,DURASLEEVE devices were repeatedly openedagainst 5000 psi (345 bar) differential pressurewith no seal damage.

Low shifting forces

DURATEF ECMnon-elastomer seals

High pressureequalizing ability

Lower shifting forces are shown

dramatically in the chart above. Even

after shifting the DURASLEEVE 100 times,

shifting force with DURATEF ECM seal,

the new Engineered Composite Material,

was 80% less than with PEEK seals.

Test conditions - 5,000 psi(345 bar) external pressure,325F (165C)

ShiftingForce(lbs)

*The Engineering Test Lab used the nitrile seal as a benchmark to compare the PEEK seal and the engineered composite seal.

3000

2500

2000

1500

1000

500

0

PEEK SealEngineered

Composite Seal

Nitrile Seal*Engineered

Composite SealPEEK SealNitrile Seal*

Halliburtons new non-elastomer DURASLEEVE

circulation/production sleeve is the new standard forsliding sleeve performance. Innovative design

features offer improved durability andperformance.

HN00189

Built-in Halliburtonnipple profile

Improved shifting system

Lowest total cost sleeveavailable


30/40

Equalizing FeatureEqualizing ports in theinner sleeve allow pressuredifferential between thetubing and casing toequalize before shifting tofull-open position andwithout seal damage.

HN00191

HN00190

Built-in Landing NippleA Halliburton nipple profile andpolished pack-off area serve as alocation to install flow controldevices. Available profiles includeHalliburtons Otis X, R, FBN, andRPT. Additional nipple profiles

are available on request.

Improved Port ConfigurationChance of seal damage is reduced bya new equalizing port configuration.Port size is optimized to preventdamage to equalizing shifting tools

and to minimize time.

Improved SealsHalliburtons exclusive DURATEFnon-elastomer EngineeredComposite Material seal providespositive pressure sealing throughrepeated sleeve operation.Stationary packing arrangement isless susceptible to damage duringsleeve travel.

High Strength Body ThreadsThese threads make the sleeves easierto disassemble, even in exoticmaterials. This cuts the time required,helps prevent galling of threads andreduces the cost to redress.


31/40

CPP5622 1995 Halliburton Company Printed in U.S.A.


FOR MORE INFORMATION, CONTACTYOUR LOCAL HALLIBURTONREPRESENTATIVEYOUR SOLUTION CONNECTION

SM

.

North AmericaHalliburton Center5151 San FelipeHouston, Texas 77056USAPhone: 713-624-7474Fax: 713-624-7580

Europe / AfricaHalliburton150 The BroadwayWimbledonLondonSW19 1RX EnglandPhone: 0181-544-5000Fax: 0181-544-6655

Latin AmericaHalliburton Center5151 San FelipeHouston, Texas 77056USAPhone: 713-624-3300Fax: 713-624-3320

Middle East / CIS1101-1104 Al Moosa TowerAbu Dhabi HighwayP.O. Box 3111DubaiUnited Arab EmiratesPhone: 971-4-310666Fax: 971-4-310442

Asia / Pacific / China100 Gul CircleJurong, Singapore 2262Republic of SingaporePhone: 65-861-6811Fax: 65-862-3453

Sliding Sleeve Feature Scorecard

Halliburton DURASLEEVE

Sliding Sleeve

Conventional

Sliding Sleeve

Maximum Recommended 5000 psi 1500 psiEqualizing PressureDifferential

Average Shifting Force 1500 lbsTo Open Or Close*

Staged Equalizing Tool Yes NoTo Prevent PrematureOpening

Non-Elastomer Seals Yes YesAnd Body Joint Connections

Anti-Galling Body Joint Yes NoThread Profile ForCheaper, Faster Redress

* Note: Shifting force for comparison was measured at zero pressure differential with sleeves innew condition. Actual shifting force may vary due to well conditions and length of time installed.

*Note: Shifting force for comparison was measured at zero pressure differential with sleeves innew condition. Actual shifting force may vary due to well conditions and length of time installed.

Sliding Sleeve Feature ScorecardSliding Sleeve Feature Scorecard

Halliburton DURASLEEVE

Sliding Sleeve

Conventional

Sliding Sleeve



Average Shifting Force 1500 lbsTo Open Or Close*

Staged Equalizing Tool Yes NoTo Prevent PrematureOpening

Non-Elastomer Seals Yes YesAnd Body Joint Connections

Anti-Galling Body Joint Yes NoThread Profile ForCheaper, Faster Redress

CN02366


32/40

Economical And Reliable Completion Products

Monolock Lock SystemLower Cost Options And Improved Reliability WithThe Halliburton Monolock Lock System

HALLIBURTON

The ultimate solution to setting flow controls orplugs in monobore completions may be the abilityto set a device anywhere in the tubing stringachallenge that Halliburton has met through its

unique nippleless lock system, the MonolockLock System. Halliburtons Monolock is designedto be set anywhere in a given size of tubing, casing,or liner. It differs from a conventional lock mandrelin that the Monolock does not require either a

profile or a seal bore in the tubing string. Also, the

Monolock is retained in position by slips ratherthan keys. It may be used in conjunction with theHalliburton FBN Fullbore Nipple System or anyother selective nipple and lock system.

The Monolock plug was designed for

retrievable bridge plug applications and can beadapted to install bottomhole pressure gauges andother flow control devices. Also, the Monolock canbe used to plug tubing below the hanger forwellhead repairs. It can be run in wells with

landing nipples or other types of restrictions aslong as the run OD is smaller than the restriction ID.

The Monolock may be set hydraulically on coiledtubing, explosively on conductor line or slickline(in conjunction with an electronic triggering

device), or electro-mechanically on slickline.Setting the Monolock with a Downhole Power Unit(DPU) and running/retrieving tool on slicklinecan help lower installation and retrieval costs.Once set, the Monolock and associated plug assemblyholds pressure from either direction. In fact, the

Monolock is designed to withstand differentialpressures of up to 10,000 psi. The Monolock can beretrieved by slickline or coiled tubing.

Single-Piece Sealing Element

One Piece Barrel Slip

Monolock Plug

CN02001


33/40

Features and Benefits

Lock is designed to be run and retrieved on slickline. Cost savings result from the ability to plug a well without rig intervention by using lower-cost

options such as slickline. Setting mechanism permits lock to be set anywhere in the tubing, liner, or casing. Slip design permits setting in unsupported pipe without deforming the pipe. Slip configuration ensures centralized setting, even in high-angle wells. Seal element is a one-piece design, making it suitable for a wide range of conditions. Seal element is located above the slip to ensure the slip is kept free of debris. Interface between the releasing mechanism and seal element provides element retractability

during retrieval process. Belleville spring energizer provides sufficient force across the seal element to create strong

initial sealing capability during pressure reversals across the assembly.

Specifications

Tubing/Casing Data Monolock Data

Tbg/Csg Weight Nominal Drift Standard Max OD Fish Pressure Part

Size (lb) ID (in.) (in.) Nipple (in.) Neck Rating Number

(in.) ID (in.) (in.) (psi)

3.5 9.3 2.992 2.867 2.813 2.78 1.810 8,100 21ML27810

4.5 12.6 3.958 3.833 3.813 3.78 1.380 6,700 21ML37810

4.5 13.5 3.920 3.795 3.813 3.78 1.380 7,200

4.5 13.5 3.920 3.795 3.688 3.66 1.380 7,200 21ML36610

4.5 15.5 3.826 3.701 3.688 3.66 1.380 8,300

5 15 4.408 4.283 4.125 4.09 1.380 6,600 21ML40910

5 18 4.276 4.151 4.125 4.09 1.380 8,100

5 18 4.276 4.151 4.000 3.97 1.380 8,100 21ML39710

5.5 17 4.892 4.767 4.562 4.53 1.810 6,200

5.5 20 4.778 4.653 4.562 4.53 1.810 7,300 21ML55010

5.5 23 4.670 4.545 4.562 4.53 1.810 8,000

7 23 6.366 6.241 6.000 5.97 2.310 5,000

7 26 6.276 6.151 6.000 5.97 2.310 5,800 21ML59710

7 29 6.184 6.059 6.000 5.97 2.310 6,500

7 26 6.276 6.151 5.963 5.92 2.310 5,800

7 29 6.184 6.059 5.963 5.92 2.310 6,500 21ML59210

7 32 6.094 5.969 5.963 5.92 2.310 7,200

7 32 6.094 5.969 5.750 5.72 2.620 6,700

7 35 6.004 5.879 5.750 5.72 2.620 7,200 21ML1

7 38 5.920 5.795 5.750 5.72 2.620 7,200

H00018 1996 Halliburton Company Printed in U.S.A.




34/40


35/40

H00039 1996 Halliburton Company Printed in U.S.A.


Tubing Size

NippleProfile

Seal Bore(Minimum ID)

IN MM

2 3/8

1.5001.6251.7811.875

.750

.750

.750

.750

1.5601.6851.8411.935

2.0002.1882.313

1.1201.1201.120

2.0602.2482.373

2.0002.1882.313

1.1201.1201.120

2.0602.2482.373

3.0003.1253.313

1.7501.7501.750

3.0603.2103.395

3.4373.5623.6883.7503.8134.000

1.9401.9401.9401.940

1.9401.940

3.5203.6503.7703.807

3.8954.090

4.1884.3134.4374.5004.5624.688

2.7502.7502.7502.7502.7502.750

4.2704.3954.5204.5504.6504.760

5.5005.6255.7505.875

5.9636.250

38.1041.2845.2447.63

50.8055.5858.75

50.8055.5858.75

76.2079.3884.15

87.3090.4793.6895.2596.85

101.60

106.38109.55112.70114.30115.87119.08

139.70142.88146.05149.23

151.46158.75

3.6803.6803.6803.680

3.6803.680

19.0519.0519.0519.05

28.4528.4528.45

28.4528.4528.45

44.5044.5044.50

49.2849.2849.2849.2849.2849.28

69.8569.8569.8569.8569.8569.85

93.4893.4893.4893.48

93.4893.48

5.5855.7105.8405.940

6.0256.330

39.6242.8046.7649.15

52.3257.1060.27

52.3257.1060.27

77.7281.5386.23

89.4192.7195.7696.7098.93103.89

108.46111.63114.81115.57118.11120.90

141.86145.03148.34150.88

153.04160.78

2 7/8

3 1/2

4 - 4 1/2

4 1/2 - 5

5 1/2

7

Lock Mandrel

ID

IN MM

OD

IN MM

RPTTM Profile and Lock DimensionsOperation

Halliburton RPT No-GoLanding Nipples provide ameans of running a seriesof nipples in a tubingstring when a stepdowncompletion with a largethrough-bore is required.The Halliburton LandingNipples are designed toaccept Halliburton RPTLock Mandrels with a min-imum rated working pres-sure of 10,000 psi, both

upstream and downstream.

Since the Lock MandrelNo-Go locates on top of thenipples polished bore,there are no secondaryrestrictions normally asso-ciated with bottom no-goprofiles. The No-Go Nippleprovides positive locationof the lock and minimizesthe possibility of misruns.Nipple bores are stepped

down in approximately1/8-inch increments tominimize loss of through-bore ID. Halliburton RPTLock Mandrels within agiven size range aredesigned to use the samerunning tool, pulling tool,and equalizing prong.


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Features and Benefits testing tubing can be accomplished

without delay or problemsassociated with other pluggingmethods

soft expend feature minimizesshock damage to formation

reduces completion costs byeliminating trips to install andretrieve plugging device

water used to dissolve plug iscarried with the tool

a diaphragm is run in the top of

the tool to keep debris off plugmatrix

full nonrestrictive ID afterexpending plug

maximum particle size after theplug material has disintegrated is1 mm, eliminating any well debris

can be mechanically activated bywireline as a backup

multiple pressure cycle capability hold differential pressure from

above and below

automatic expend after lastpressure cycle reduces well risk, reduces number

of slickline or CTU trips in the hole,allows multiple pressure tests priorto expending

Cost-effective completion technology

Mirage Disappearing Plug

H A L L I B U RTO N

The Halliburton MirageDisappearing Plug is aplugging device designed torun as an integral part of thetubing. The plug can be usedto set a hydraulic-set packeror to test the tubing string.It is activated by hydraulicpressure, eliminating theneed to use wireline orcoiled tubing to run and

retrieve the plugging device.Once the plug has beenexpended, the plug materialwill dissolve anddisintegrate leaving fulltubing ID through the plug.A fill sub is run above themirage plug when tubingautofill is required.

Applications

horizontal and high angle wellswhere slickline or CTUintervention after completion isundesirable

setting production and isolationpackers

testing tubing wells where retrievable plug

after use is undesirable

M i r a g e Disappearing Plug


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Applications uniquely designed for wireline-

retrievable SCSSV applications high flow rates

Features

lock mandrel can only lock inthe nipple after control lineintegrity is established

no shear pins in the running tool running tool can be released

only after lock mandrel locks

and SCSSV is operable large ID locking sleeve locks in the

direction of flow optimum pressure rating design

on lock mandrel anti-vibration ring in lock

mandrel

Benefits

helps eliminate the possibility ofsubsurface safety valves being

left downhole without properinstallation or without controlline pressure integrity

no shear pin damage to safetyequipment, seals, or sealingbores

no presetting or false setindications from premature pinshearing

helps avoid a possible flow-outof the subsurface safety valvesto surface

minimal metal-to-metal abrasion

from vibration lock system is protected from

accidental unlocking by slicklinetools passing through the ID

Reliable subsurface flow control technology

Safety SetLock Mandrel System

H A L L I B U RTO N

Halliburtons SAFETYSET lockmandrel system is a drive-down,

jar-up-to-set, no-go type systemdesigned specifically for surface-controlled subsurface safety valve(SCSSV) applications. Thispatented system consists of aSAFETY SET lock mandrel,running tool, and unlocking tool.The SAFETY SET lock mandrelsystem is designed to help ensurevalve-set integrity and hydraulic

control communication to thesafety valve.

The design features a lockingsleeve that moves upward in thedirection of flow to establish alocked safety valve. This lockingallows unlimited drive-downaction without the possibility ofpresetting the lock while it travelsdownhole. A no-go shoulder onthe lock mandrel providespositive locating within thelanding nipple.

This system is designed tominimize operator guess work atthe surface by requiring twoindependent conditions to existbefore the running tool willrelease. The SCSSV must bepressured open for the lock keysto expand. Only when the lock-ing sleeve is locked in place willthe running tool release. A run-

ning tool retrieved to the surfacewithout the lock and valve indi-cates a functional valve securelylocked into the landing nipple.

Safety Set

Lock Mandrel System

Options designs are available for all RQ

and RPT landing nippleprofiles

models can be designed to landand lock in any safety valvelanding nipple with a no-go ID

staggered-bore SAFETYSET lockmandrels are available for safetyvalve landing nipple installations


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TOOL DEMO

LITERATURE

STPP

SINGLE-TRIP

PerfPac

COMPLETION

SYSTEM

STPP

SINGLE-TRIP

PerfPac

COMPLETION

SYSTEM
http://cybertls/Stpp.exehttp://cybertls/Stpp.exehttp://cybertls/STPP/demo.avihttp://cybertls/Stpp.exehttp://cybertls/STPP/demo.avi


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STPPTMSingle-Trip PerfPac Completion System

Save rig time, cut fluid loss, stop well control problems

Perforate, complete and clean up in a single run

Separate trips for perforation, completion, and cleanup are no longer required. Halliburtons Single-TripPerfPac System provides cost effective, single runcompletions with an innovative design that combines all

required equipment on a single string.

Single run system saves time and money

Save rig time.Halliburtons single-trip completionsaves a minimum of two runs in the hole forfaster completions.

Begin production sooner. The decreased number ofruns means the well can be brought on line earlier.

Meet all completion needs. The Single-Trip PerfPacSystem is extremely flexible. It can be configured toperform a water frac, high rate water pack, FracPac,Slurry Pac, or a gravel pack.

Minimize fluid loss, avoid well control problems.Single-trip speed means faster completions that helpprevent excessive loss of expensive completion fluids tothe formation.

Breakthrough performance using proventechnology

MPT gravel pack service tool prevents premature

setting of the gravel pack packer during perforation,allowing the packer and TCP guns to be run together. Anon-rotating tool, it eliminates the need to rotatedownhole to separate from the gravel pack packer. Italso easily converts to a washdown tool.

Big bore packer accommodates a larger ID/OD ratio,allowing the TCP guns to pass through the sump packer.

Champ Packereliminates the need to displace theentire wellbore with nitrogen. By confiningdisplacement to the tubing, less nitrogen is used andbetter control of the underbalance pressure and TCPfiring is achieved.

OMNI Valveeliminates the need to move tubing tokill the well after perforating.

P-110 grade blankprevents the collapse of the screenand blank.

TCP gun systemsare available in a wide variety of sizesto optimize completion performance.

This Single-Trip PerfPac System was configured for a shallow,high-pressure environment. Variations of the system are available forhighly-deviated, normal and below-normal pressured wells.

Champ IV

MPTSetting

Tool

Versa-TrievePacker

Fluid LossFlapper

Blank

Screen

SumpSeals

TCP

BBPSumpPacker

Versa-TrieveProductionPackerw/FootValve

Versa-TrievePackerw/FluidLossFlapper

Perforating FracPacking Completing

HN01104


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HalliburtonYour Solutions ConnectionSM

Contact your local Halliburton representative for moreinformation on how an efficient Single-Trip PerfPac System

completion can save you money.

Efficient Single-Trip completionsaves Texaco over $1.3 million

Offshore Louisiana: Texaco was using ZnBr2to control high pressure in a well with TVDof 6,300 ft and BHP of 7,000 psi. Excessiveamounts of the expensive completion fluidwere being lost to the formation.

Halliburton designed a Single-Trip PerfPacSystem to minimize rig time and cut fluidloss. The system performed TCP perforatingand a FracPac sand control treatment duringa single run.

The completion was performed as planned,saving over 3-1/2 days of rig time andhundreds of barrels of ZnBr2. The entirecompletion saved an estimated $1.376million compared to a previous completionin the same field. The well is producing2,000 BOPD and 1.446 MCFD sand free.

compsim.pdf

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