Post on 04-Jun-2018
8/14/2019 compsim.pdf
1/40
COMPLETION PRODUCTSCOMPLETION PRODUCTS
PACKERS
SURSUFACE
FLOW CONTROL
SYSTEMS
SUBSURFACE
SAFETY VALVES
8/14/2019 compsim.pdf
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
INTRODUCTIONSIMULATOR LITE
INTRODUCTIONSIMULATOR LITE
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.avi8/14/2019 compsim.pdf
3/40
For more information on Halliburton Products and Servicesvisit our Home page at http:/ / www.Halliburton.com
INTRODUCTIONSIMULATOR LITE
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.avi8/14/2019 compsim.pdf
4/40
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
8/14/2019 compsim.pdf
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
8/14/2019 compsim.pdf
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
8/14/2019 compsim.pdf
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
8/14/2019 compsim.pdf
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
8/14/2019 compsim.pdf
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.
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.
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)
8/14/2019 compsim.pdf
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
8/14/2019 compsim.pdf
11/40
CPP5619 1995 Halliburton Energy Services 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.
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
8/14/2019 compsim.pdf
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
8/14/2019 compsim.pdf
13/40
8/14/2019 compsim.pdf
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
8/14/2019 compsim.pdf
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
8/14/2019 compsim.pdf
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
8/14/2019 compsim.pdf
17/40
SUPERIOR
PERFORMANCE
SUPERIOR
PERFORMANCE
For more information on Halliburton Products and Servicesvisit our Home page at http:/ / www.Halliburton.com
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.avi8/14/2019 compsim.pdf
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
8/14/2019 compsim.pdf
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.
8/14/2019 compsim.pdf
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
8/14/2019 compsim.pdf
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
8/14/2019 compsim.pdf
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
8/14/2019 compsim.pdf
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.
8/14/2019 compsim.pdf
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
8/14/2019 compsim.pdf
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.
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.
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.
8/14/2019 compsim.pdf
26/40
TOOL DEMO INTRODUCTION
INTRODUCTION
INTRODUCTION
For more information on Halliburton Products and Servicesvisit our Home page at http:/ / www.Halliburton.com
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.avi8/14/2019 compsim.pdf
27/40
For more information on Halliburton Products and Servicesvisit our Home page at http:/ / www.Halliburton.com
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.exe8/14/2019 compsim.pdf
28/40
Improved Performance With Non-Elastomer Design
DURASLEEVE CIRCULATION/PRODUCTION SLEEVE
HALLIBURTON
8/14/2019 compsim.pdf
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
8/14/2019 compsim.pdf
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.
8/14/2019 compsim.pdf
31/40
CPP5622 1995 Halliburton Company 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.
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
Maximum Recommended 5000 psi 1500 psiEqualizing PressureDifferential
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
CN02366
8/14/2019 compsim.pdf
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
8/14/2019 compsim.pdf
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.
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.
8/14/2019 compsim.pdf
34/40
8/14/2019 compsim.pdf
35/40
H00039 1996 Halliburton Company 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.
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.
8/14/2019 compsim.pdf
36/40
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
8/14/2019 compsim.pdf
37/40
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
8/14/2019 compsim.pdf
38/40
For more information on Halliburton Products and Servicesvisit our Home page at http:/ / www.Halliburton.com
INTRODUCTIONSIMULATOR LITE
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.avi8/14/2019 compsim.pdf
39/40
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
8/14/2019 compsim.pdf
40/40
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.