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WCP1-018
Packers
Overview
y Packer functions
y Main Packer Families
y Retrievable Packers
y Permanent Packers

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y Multizone Packers
y Packer Selection Process

WCP1-018 Packers – slide 2

Production Packer – Functions
y The functions of downhole packers can be summarized as:
y Annular isolation – providing a long-term pressure and fluid
barrier which:
y provides improved hydraulic (production) conditions
y enables tubing mounted safety valves

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y provides a second conduit

Note: Seals and component materials must be compatible with

reservoir fluids

WCP1-018 Packers – slide 3

Production Packer - Functions (2)
y Downhole anchor
y providing downhole stability and control
y Casing string protection
y protecting casing/liner from corrosive fluids
y providing a renewable production conduit

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y Downhole safety and control
y e.g., temporary tubing plugs
y Zone separation
y e.g., multiple packer/multiple string
y regulatory monitoring of specific zones

WCP1-018 Packers – slide 4

Production Packer - Functions (3)
y Zone separation
y Control of differential pressure between zones (preventing cross
flow)
y Artificial Lift
y Separate conduit/pathway for injection gas or power fluid

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y Selective treatment
y Preventative (e.g., scale) and remedial treatments
y Remedial/repair
y seal/bypass damaged area
y isolation of production zone

WCP1-018 Packers – slide 5

Typical Packer

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Sealing element Slips Casing wall

Cone Internal slips

WCP1-018 Packers – slide 6

Generic mechanism
To perform two things must happen.

y Firstly a cone must be driven behind tapered slips to force

the slip out and into the casing wall.

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y Secondly a sealing element must be compressed to effect a
seal against the casing wall.
y The two most important basic components are therefore the
slips and sealing element.

WCP1-018 Packers – slide 7

Generic mechanism
y Packer slips can be unidirectional or may be designed to
resist force from either direction
y Sealing elements may be one piece construction or
composed of multiple elements of different degrees of
hardness

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WCP1-018 Packers – slide 8
Production Packers – Types
y Production packers categorized by:
y Retrievability
y retrievable, semi-permanent, permanent
y Setting mechanism
y mechanical, hydraulic, wireline

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y Production conduit
y single, dual, multiple/special
y Basic categories (for this presentation)
y Retrievable packers
y Permanent packers
y Dual packer systems

WCP1-018 Packers – slide 9

Retrievable Packers
y Retrievable packers preferred for applications where:
y Completion life is relatively short
y Wellbore conditions are non hostile
y e.g., temperature, pressure, H2S
y

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Setting depth shallow to medium
y Low to moderate differential pressures
y Straight wellbore or moderate deviation
y Multiple zones are to be produced

WCP1-018 Packers – slide 10

Retrievable Mechanical Set Packer
y Typically requires rotation (±1/2
turn at tool) and tubing set-
down to set
y Tubing weight maintains seal
and anchor

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Hold down slips (hydraulic)
y Unset by picking up
y May be reset several times –
similar design and operation to Packing elements
packers used for well service
work
Bottom (hold-up) slips

Continuous mandrel

WCP1-018 Packers – slide 11

Mechanical Set – Advantages
y Cost
y generally less than other packer systems
y Repeat setting
y packer can be set, released, moved and reset without removal
and redressing

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y Versatility
y one packer can be used with multiple casing weights
y compression, tension or bi-directional set options
y Length
y can generally be used in situations where dog-legs or extreme
deviations are encountered

WCP1-018 Packers – slide 12

Mechanical Set – Disadvantages
y Limited capacity
y high forces can unseat and release the packer
y Setting
y the setting (and releasing) mechanisms may not allow packers to
be run in tandem

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y generally requires rotation and tubing movement to set
y no provisions for “stored energy” to aid in packer seal and anchor
y injection operations (cooling) may release the packer

WCP1-018 Packers – slide 13

Hydraulic Set Packer

y Hydraulic set – no rotation

required
y ±3500 psi applied to plugged
tubing string Packing elements

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y Straight pull release (once
only)
y Single and dual application
compatible Slip (top and bottom)
assembly

Continuous mandrel

WCP1-018 Packers – slide 14

Hydraulic Set Packer – Applications
y Hydraulic set packers are preferred where:
y Medium to high pressure single string completions
y Dual completions
y Selective single completions
y

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Reservoirs with anticipated heavy workover activities
y Applications where it is not possible to rotate tubing

WCP1-018 Packers – slide 15

Hydraulic Set Packer – Advantages
y Hydraulic set retrievable packers have some advantages
over mechanical set retrievables
y Setting
y energy is stored in the ratchet mechanism
y

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packer set is not dependent on continual tubing weight
y space out operation easier without tubing movement
y more accurate placement and space out

WCP1-018 Packers – slide 16

Hydraulic Packer – Disadvantages
y Setting
y If the packer is prematurely or incorrectly set, it must then be
pulled to be redressed
y Cost
y Flexibility

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WCP1-018 Packers – slide 17
Permanent Packers
y Permanent packers run by: Latch profile
y Wireline
y Tubing Seal-bore extension
y Coiled tubing

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y Permanent packers set by:
y Hydraulic (tubing) Packing elements
pressure
y Mechanical mechanism
y Electric wireline

Bottom sub/adapter

WCP1-018 Packers – slide 18

Permanent Packer – Applications
y Hostile operating conditions, e.g.,
y differential pressure >5000 psi
y temperature >300°F
y H2S > 10%
y Medium or deep set applications

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y Deviated and extended reach wells
y Selective single completions
y setting point correlated by wireline
y Dual completions with parallel flow tubes
y Sump packer for gravel packer operations

WCP1-018 Packers – slide 19

Permanent Packer – Configurations

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Seal-bore packer

Upper seal bore receptacle

Lower seal-bore extension

WCP1-018 Packers – slide 20

Permanent Packer – Configurations

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Lower seal-bore extension Lower seal-bore extension

WCP1-018 Packers – slide 21

Permanent Packer – Configurations

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Seal-bore packer with Permanent packer with
lower seal-bore extension an extra-long upper
and liner top seal-bore seal receptacle for
assembly extreme movement
applications

WCP1-018 Packers – slide 22

Permanent Packer – Retrieval
y Milling assembly with
spear/retrieving assembly Flow (circulation divider)

y Circulation at mill and through Mill shoe with wash pipe

spear adapter(s) to suit size of
packer and seal-bore
y Spear engaged when upper extension

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slips milled
y Incorporates safety release Lower section of packer
system for spear retrieved when upper slips
are removed

Spear/packer retriever
engages
in packer bore or millout
extension

WCP1-018 Packers – slide 23

Seal-Bore Packers

Packer Type Camco Baker Otis Guiberson

Hydraulic Set HS, HSB, SB-3, SAB-3 Perma Drill Magnum PG

HSP-1 Magnum PH

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Mechanical Set N Perma Drill Mechanical Set
(Drillable) Magnum
Drillable S, L, LB, LO D, DA, F-1, Perma Drill Magnum G
Seal-Bore FA, FA-1 Magnum H
Retrievable Omegamatic SC-2 Cerso-Trieve UNI-X
Seal-Bore Quantum* HP Perma-Trieve
Wireline Set SOT-1, WR LOK-Set Perma-Trieve G-6, VNI, VI
Retrievable Perma-Latch ER-VI

WCP1-018 Packers – slide 24

Dual Packer Systems
Dual packer systems:
y generally require one
dual packer and one Dual mandrels
single (conventional)
packer

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Packing element
y allow production
through two tubing
strings from the same
Bi-directional
wellbore slip assembly
y enable production from
adjacent high and low
pressure zones

WCP1-018 Packers – slide 25

Packer Selection Process
Do unique conditions merit use of a
special retrievable packer or PBR? PERMANENT PACKER
(Gravel packs) SYSTEM
Are severe or hostile Yes (Multiple zones) No
conditions expected? Review:
(∆p>5000 psi and T > 300ºF) (Steam wells) •Setting method
(Axial Load > 50,000 lbs) (Liner completions) •Packer-tubing interface
(H2S > 10%) (Temporary completions) •Elastomer specifications
(High deviations) •Landing conditions
No (Fullbore access) •Talipipe requirements

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Will workovers likely involve Yes
packer removal within 10 No
Review options and QA/QC programme
years or fullbore access to to make sure that equipment is suitable
pay zone? PBR COMPLETION SYSTEM
Review
Yes
•Casing or liner
Do throughbore Yes Could a PBR be used to provide Yes •Landing conditions
requirements preclude use of fullbore access to pay zone? •Elastomer specs
standard retrievable packers?
•Nipple arrangements
No
CONSIDER OPTIONS
Is access to zone of interest limited Yes •Roll or swage casing RETRIEVABLE PACKER
by buckled or collapsed casing? •Sidetrack well SYSTEM
•Use short permanent packers Review:
•Consider inflatable packers for
•Hold-down method
No limited differentials
•Equalization
•Setting method
•Positioning
•Internal seals
•Landing conditions

WCP1-018 Packers – slide 26

 Packer PBR Anchor
Is it desirable to isolate
Is it essential to isolate
annulus downhole? Is annular flow Evaluate
annulus downhole? No No No Will well be Yes
(Flow improvement, most cost effective packerless
(Regulations, safety, produced on rod
corrosion control and productive than completion with
corrosion control pump within 5 years?
isolate squeeze tubing flow? tubing anchor
or use of annulus)
perforations or liner?)
Yes No Packerless completion
Yes Yes unanchored tubing
Will zone be produced on Evaluate gas venting options
Yes
pump with free gas at intake (packerless completions, or annulus

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within 5 years vs. multi-strings)

No

Is fullbore access to a liner required? Yes Does a PBR offer advantages over a Yes
(Access to small bore pipe, scale/asphaltene large bore packer? (eg max through bore Polished Bore Receptacle
removal, or to avoid flow restrictions) or liner cap isolation) (PBR) Completion

No No
PACKER COMPLETION
Can packer be set well above top pay without limiting functional Yes
Consider benefits and problems with shallow
requirements for isolation, well kill, artificial lift and
setting depth (below SSV, above top of liner
flow optimization?
and above recompletion targets)
No
Yes PACKER COMPLETION
Will production logging be required
Set packer so tubing shoe is
under flowing conditions?
50 to 100 ft above perforations

PACKER COMPLETION
No Minimum safe distance between packer
and perforations 5 ft for wireline correlations
0.2% depth for tubing packers

WCP1-018 Packers – slide 27

Packer Selection
Exit
Has PBR completion been selected? Is a packer and tailpipe required within the liner for isolation? No
No Yes
Set permanent packer and tailpipe in liner
Has a liner been installed? Yes Good seal in liner overlap? No
No Yes Set packer
No above liner
Are production logs to be run?
Set packer at max depth allowing for tailpipe

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Yes

Set packer above liner top

Yes Is H2S present?

No
Check seal and Is packer set below SSSV? No Set packer below SSSV
metal selection
Yes
Packer must have large enough bore
Is tubing conveyed perforating to be used? Yes to pass large guns or be retrievable

Do packer force calculation No

Is packer P > 5000 psi? No Is temp at set No Is H2S or No Are regular workovers Yes Does retrievable have
depth >225°F? CO2 present? needed? good reliability?
Yes
Yes Yes No No Yes
Is temp at set depth <160°F?
Yes No
Run
Check seal selection retrievable
Permanent Packer packer

WCP1-018 Packers – slide 28

Packer-To-Tubing Guide
Pressure Diff (psi) Environmental Compatibility
Seal Type Temp Non Unloading H2S Oil Light Bromide High pH CO2 Amine
Range F Unloading Base Brine Comp Comp Decomp Inhibitors
Comp Comp pH >10
Nitrile Chevron 32-300 10,000 NO
70 Hard 32-200 5,000 5,000 NO OK OK NO NO OK NO
Nitrile Bonded
90 Hard Nitrile 32-300 10,000 5,000
Bonded

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95 Hard Viton 32-250 10,000 5,000 5% OK OK OK NO OK NO
Bonded
V-Ryte 32-300 15,000 NO 15% OK OK OK NO Note #1 NO
32-400 5% <200°F OK
A-Ryte 80-300 15,000 NO 20% NO OK OK OK Note #1 OK
80-450 7%
A-HEET 80-300 15,000 NO 20% NO OK OK OK Note #1 OK
80-450 7%
R-Ryte or 200-400(2) 10,000 NO 15% Note #4 OK OK OK OK OK OK
Molyglass 325-450 (2) 7%
Seal-Ryte 40-400 15,000 NO 15% Note #4 OK OK OK OK Note #1 OK
40-450
K-HEET 100-550 15,000 NO Note #3 OK OK OK OK Note #1 OK
Note #1: The elastomeric seals in these units may be susceptible to explosive decompression, however, explosive decompression does not usually occur while
seals are in service.
Note #2: Refer to Baker Technical Data Manual, Unit No 8218-3 for complete temperature range information.
Note #3: There are no known H2S limitations below 550°F.
Note #4: For temperatures below 400°F and more than 15% H2S, contact Houston Engineering Department for additional information

WCP1-018 Packers – slide 29

Environmental Compatibility Guide

Environmental Compatibility

Material1 Temp °F H2S Oil Base/ Light Bromide CO2 Amine Solvents2 High pH
Diesel Brine Comp Decomp Inhib. Max Exp Comp Fluids,
Comp Comp Time pH >10
Nitrile to 175 100 ppm OK OK NO OK OK 6 hours OK

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3
to 300 NO NO 4 hours NO (pH <10
OK to 250°F)
Viton™ to 200 20% OK OK
to 300 15% OK OK OK OK NO 24 hours NO
450 max 5% NO 4 hours
Aflas™ to 200 limit unknown OK 6 hours
to 300 20% NO OK OK OK OK 4 hours OK
450 max 7% NO NO
Note #1 These recommendations are based on expected long term completions
Note #2 Some examples of solvents are: xylene, toluene, methanol
Note #3 Some permanent packer applications may allow use of nitrile above 300°F. Contact AEG

WCP1-018 Packers – slide 30

R&S Compatibility Guide

Environmental Compatibility

Material1 Temp °F2 H2S Oil Base/ Light Bromide Amine Acids Solvents4 High pH
Comp Brine Comp Inhib Max Exp Max Exp Comp Fluids,
Comp Time Time pH >10
Nitrile to 175 OK OK OK NO OK 8 hours 6 hours OK

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400 6 hours 4 hours 24 hours
Viton™3 to 175 OK OK OK OK OK 24 hours 24 hours NO
350 NO 4 hours 4 hours
Aflas™3 to 175 OK NO OK OK OK 48 hours 4 hours OK
350 8 hours NO
EPDM3 to 500 OK NO OK OK OK OK NO OK
Note #1 These recommendations are for relatively short term exposure R & S applications only. (Typically <30 days). Longer term
completion applications should follow other guidelines
Note #2 Pressure ratings are dependant on size and type of tool and are less related to chemical resistance than temperature.
Refer to Tech Manual for pressure ratings.
Note #3 These materials are special order only. Long load times and/or product development are likely.
Note #4 Some examples of solvents are: xylene, toluene, methanol.

WCP1-018 Packers – slide 31

Business Model and “Field Life Cycle”
Useful for planning and execution.
Breaks the Field Life Cycle down into discrete business processes.
Each business process should have a well defined product
(deliverable) and lead to a clear decision point (Key decision)

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Business process Deliverable Key decision
EXIT
Activity Product ?
CONTINUE
Next activity ETC Breaking activities down into manageable
units and defining their purpose in
manageable bits is essential to effective
planning

WCP1-018 Packers – slide 32

Module Control

Module ID WCP1_018 Packers

Version 1a

Course WCP-1

Schlumberger Private
Date Created March 26, 2003

Creator Willem van Adrichem, HTC

Checked by

Date Checked

Comments

WCP1-018 Packers – slide 33