Packer Systems Catalog
Introduction
Since 1940, when we introduced the industry’s irst completion packer, Baker Hughes has set the standard for innovation and performance in
packer technology. Today, when your projects push the edge of the completion technology envelope, you can count on our packers to reliably
deliver unsurpassed service, performance, and value. Baker Hughes packer solutions cover the spectrum of applications, from single, selective,
and dual completions to extreme high-pressure/high-temperature (XHP/HT), deepwater, extended-reach, multilateral, and intelligent well systems.
The Center for Technology Innovation (CTI) in Houston is our primary center of excellence for completion technology, including packers. Here,
engineers and scientists create new solutions for the industry’s toughest completion and production challenges. Research and development focus
on cased and open-hole completion technologies, iber optics, and downhole electronics, nanotechnology, and materials science. The CTI’s four
dynamic in-ground test cells are the world’s highest rated for pressure and temperature, at 40,000 psi (2757 bar) and 700°F (371˚C). The 75-ft
(21.3-m) test cell towers make it easy to manipulate 40-ft (2.2-m) joints of large-diameter casing into and out of the bay. In addition to the CTI,
and other facilities in Houston, research and engineering for completions products and services is conducted in Broken Arrow, Oklahoma, and
Aberdeen, Scotland.
The Center for Technology Innovation in Houston, TX
i
Alphabetical Product Index
Applications
MJS Thermal Packer .........................................................................71
Material Selection ...........................................................................1-5
Mudline Tubing Hanger.....................................................................79
Packer Performance ............................................................................6
Parallel Head .....................................................................................73
Single Zone ....................................................................................7-13
Premier Removable Production Packer .............................................66
Multiple Zone ...............................................................................14-19
Premier Removable Production Packer With Striker ........................67
Deepwater....................................................................................20-23
R-3 Double Grip Retrievable Casing Packer......................................55
High-Pressure/High-Temperature .....................................................24
R-3 Single Grip Retrievable Casing Packer .......................................55
Thermal .............................................................................................25
Reliant Series WL Wireline-Set Single-String
CO2 Injection and Waterlood ...........................................................26
Retrievable Packer .......................................................................70
Waterlood ........................................................................................27
SABRE Mechanical Set Retrievable Packer......................................61
Electric Submersible Pump ..........................................................28-30
SC-2 Retrievable Packer....................................................................68
Twin Seal Electric Submersible Pump Packer...................................76
Permanent Packer Systems
Baker Retainer Production Packer With Alas Element System .......48
Casing Cleanup Systems
D and DB Retainer Production Packers .............................................34
Casing Scraper ..................................................................................82
DA and DAB Retainer Production Packers ........................................36
H Wire Feeler and Junk Catcher .......................................................82
DV Retainer Production Packer .........................................................38
F-1 and FB-1 Retainer Production Packers ........................................39
Packer Setting System
FA, FAB, FA-1 and FAB-1 Retainer Production Packers ....................40
BH and BHH Setting Tools ...............................................................86
FB-3 High-Pressure Retainer Production Packer ...............................42
E-4 Wireline Pressure Setting Assembly .........................................83
Granite No Downstroke, Hydraulic-Set Retainer
E-5 HP/HT Wireline Pressure Setting Assembly ..............................84
Production Packer.........................................................................43
J and B-2 Hydraulic Setting Tools ....................................................85
SAB-3 and SABL-3 Hydraulic-Set Retainer Production Packers .......46
SB-3 Hydraulic-Set Retainer Production Packer ...............................44
Packer Retrieving Systems
Signature D and DB Retainer Production Packers ............................33
Premier Workstring Retrieving Tool ..................................................88
S-1 Retrieving Tool ...........................................................................87
Retrievable Packer Systems
A-3 and AL-2 LOK-SET Retrievable Casing Packers..........................57
Seal Assemblies
A-5 Dual-String Retrievable Packer ..................................................74
Anchor Tubing Seal Assembly ..........................................................91
AD-1 and ADL-1 Tension Packers .....................................................51
Downhole Sealing Systems ..............................................................89
C-1 Single Grip Invertible Packer ......................................................53
E and EC Anchor Tubing-Seal Assemblies ........................................91
ElecPak Electric Submersible Pump Packer ......................................78
E, K and N Latch-In Shear Release Anchor Tubing
FH and FHL Hydrostatic-Set Single-String Retrievable Packers .......64
Seal Assemblies...........................................................................92
FLX Packoff Tubing Hanger ...............................................................80
E Snap-Latch Seal Assembly ............................................................92
G Retrievable Casing Packer .............................................................53
G Locator Tubing Seal Assembly ......................................................89
GT Dual-String Retrievable Packer ...................................................72
G Locator Tubing Seal Assembly With Spacer Tube ........................90
HORNET EL Packer ............................................................................59
Hydraulic Punch Releasable Anchor .................................................92
HORNET Packer .................................................................................59
K and N Locator Tubing Seal Nipples ...............................................89
HS Hydraulic-Set Single-String Retrievable Packer .........................62
K, KC, KC-1 and KC-2 AnchorTubing-Seal Nipples
Seal Assemblies...........................................................................91
ii
Alphabetical Product Index
L, LE and LM Locator Tubing Seal Assemblies
Safety Joints
With Spacer Tube.........................................................................90
B Shear-Out Safety Joint ................................................................109
Locator Tubing Seal Assembly ..........................................................89
C Rotationally Locked Shear-Out Safety Joint ...............................109
M Anchor Tubing-Seal Assembly......................................................91
Safety Joint .....................................................................................108
N and NM Anchor Tubing Seal Assemblies .....................................91
Shear-Out Safety Joint ...................................................................108
Ratcheting Muleshoe ........................................................................93
Retrievable Packer Bore Receptacle .................................................96
Parallel Flow Systems
Snap-In/Snap-Out, Set-Down-Activated,
F Parallel Locator Seal Nipple.........................................................110
Shear-Release Anchor .................................................................93
F Parallel Snap-Latch Seal Nipple ..................................................110
Seal Stacks........................................................................................94
Model A Full-Opening Anchor Parallel Flow Tube .........................110
Model A Full-Opening Parallel Flow Tube .....................................110
Seal Expansion/Disconnect Devices
Model A Parallel Anchor Seal Nipple .............................................110
Models A and A-1 Extenda-Joint......................................................98
Tubing Stability Latch (TSL)...............................................................97
Plugging Devices
C Tubing Testing Sub .......................................................................111
Disconnect Devices
E Hydro-Trip Sub..............................................................................111
L-10, R-10, L-316 and R-316 On-Off Sealing Connector Family .....100
FLOGARD Full-Bore Isolation Valve ................................................113
FLOGARD Single-Cycle Tool ............................................................113
Expansion Joints
Silhouette ........................................................................................112
E Tubing Expansion Joint ................................................................102
L Expansion Joint ............................................................................103
Packer Extensions
M Expansion Joint ..........................................................................103
Mill-Out Extension ..........................................................................115
Model A Positioning Tool ................................................................103
Sealbore Extension .........................................................................115
N Splined Expansion Joint ..............................................................102
Production String Accessories
Spacing Devices
Blast Joint .......................................................................................116
Adjustable Spacer Sub With Rotational Lock.................................105
Flow Coupling..................................................................................116
LEEJ Expansion Joint Non-Splined and Splined.............................104
Perforated Spacer Tube...................................................................116
Telescoping Swivel Sub ..................................................................105
Wireline Entry Guide With Pump-Out Plug, Shear-Out
Telescoping Space-Out Joint (TSOJ) ..............................................106
Multi-String Sealing Accessories
K Parallel Anchor Seal Nipple.........................................................107
S Snap-Latch Seal Nipple ...............................................................107
iii
Ball Seat, and Shear-Out Ball Seat Sub ....................................117
Product Number Index
Product
Family No.
Description
Casing Scraper .................................................... 82
H43210, and
Signature D and DB Retainer
SB-3 Hydraulic-Set Retainer
H43211
Production Packers ......................................... 33
H43702
E-4 Wireline Pressure Setting Assembly ........... 83
H43706
E-5 HP/HT Wireline Pressure
Product
Family No.
Description
H16105
H40906
Page
Production Packer........................................... 44
H40907, and
H40908
H40934
H41306, H41308,
SAB-3 and SABL-3 Hydraulic-Set
Retainer Production Packers .......................... 46
and H41341
H41350
H Wireline Feeler and Junk Catcher ................... 82
Retainer Production Packer ............................ 43
H44101
Safety Joint ....................................................... 108
F-1 and FB-1 Retainer Production Packers .......... 39
H44120
Telescoping Swivel Sub .................................... 105
H44125
Adjustable Spacer Sub With
Rotational Lock............................................. 105
FA, FAB, FA-1 and FAB-1 Retainer
Production Packers ......................................... 40
FB-3 High-Pressure Retainer
Production Packer........................................... 42
H41371, and
Setting Assembly ........................................... 84
H43901
Granite No Downstroke, Hydraulic-Set
and H4134
H41307, H41309,
Page
H44130
Shear-Out Safety Joint ..................................... 108
H44131
B Shear-Out Safety Joint .................................. 109
H44132
C Rotationally Locked Shear-Out
J and B-2 Hydraulic Setting Tools ...................... 85
H41574
Safety Joint .................................................. 109
H44145
E Tubing Expansion Joint .................................. 102
H44160
L Expansion Joint .............................................. 103
H44162
M Expansion Joint ............................................ 103
H44163
N Splined Expansion Joint ................................ 102
H41526, and
H44165
Model A Positioning Tool .................................. 103
H41503
H44167
LEEJ Expansion Joint Non-Splined
H41505, H41525,
D and DB Retainer Production Packers ............... 34
and H41513
H41514, H41508,
DA and DAB Retainer Production Packers .......... 36
H41534
DV Retainer Production Packer ........................... 38
(Non-Splined),
H41576, and
BH and BHH Setting Tools ................................. 86
and H44168
H41577
and Splined .................................................. 104
(Splined)
H41586
Silhouette .......................................................... 112
H44234
G Locator Tubing Seal Assembly ........................ 89
H41754
MJS Thermal Packer ........................................... 71
H44280
G Locator Tubing Seal Assembly With
H42003
G Retrievable Casing Packer ............................... 53
H42425, H42426,
Baker Retainer Production Packer With
H42432, H42525,
Spacer Tube.................................................... 90
H44387
Snap-In/Snap-Out, Set-Down-Activated,
Shear-Release Anchor ................................... 93
Alas Element System .................................... 48
H42526, H42532,
H44403
E Snap-Latch Seal Assembly .............................. 92
H42625, H42626,
H44457
Ratcheting Muleshoe .......................................... 93
H42632, H42725,
H44701
M Anchor Tubing-Seal Assembly........................ 91
H42726, H42732,
H44757
Hydraulic Punch Releasable Anchor ................... 92
H41525, H41526,
H45743
Perforated Spacer Tube..................................... 116
H41340, H41341,
H45750
Blast Joint ......................................................... 116
H40924, H40925,
H46921, and
Wireline Entry Guide With Pump-Out Plug,
H40926, H41598,
H79927
and H41599
Shear-Out Ball Seat, and Shear-Out
Ball Seat Sub................................................ 117
H48853
S-1 Retrieving Tool ............................................. 87
iv
Product Number Index
Product
Family No.
Description
Sealbore Extension ........................................... 115
H73908, and
AD-1 and ADL-1 Tension Packers ....................... 51
H49941
Mill-Out Extension ............................................ 115
H73912
H59921
C Tubing Testing Sub ......................................... 111
H73930
C-1 Single Grip Invertible Packer ........................ 53
H64101
R-3 Single Grip Retrievable Casing Packer ......... 55
H78108, and
FH and FHL Hydrostatic-Set Single-String
H64201
R-3 Double Grip Retrievable Casing Packer........ 55
H78120
H64630, and
A-3 and AL-2 LOK-SET Retrievable
H78316, H78330,
Product
Family No.
Description
H49940
Page
H64628
Casing Packers ............................................... 57
H64668
SABRE Mechanical Set Retrievable Packer........ 61
H64682
HORNET Packer ................................................... 59
H64683
HORNET EL Packer .............................................. 59
H78463,
H48807
SC-2 Retrievable Packer...................................... 68
H78467, and
H64710
Reliant Series WL Wireline-Set Single-String
H78468
(Standard
Retrievable Packer ......................................... 70
Service),
Page
Retrievable Packers........................................ 64
A-5 Dual-String Retrievable Packer .................... 74
and H78331
H78460
HS Hydraulic-Set Single-String
Retrievable Packer ......................................... 62
Premier Removable Production Packer ............... 66
H78464
Premier Workstring Retrieving Tool .................... 88
H78465
Premier Removable Production Packer
and H64711
With Striker .................................................... 67
(S&R:NACE
H78509
Service)
(Standard
GT Dual-String Retrievable Packer ..................... 72
H67116
FLOGARD Single-Cycle Tool .............................. 113
Service), and
H67121
FLOGARD Full-Bore Isolation Valve .................. 113
H78510 (NACE
H68319
Retrievable Packer Bore Receptacle ................... 96
Service)
H68347
Tubing Stability Latch (TSL)................................. 97
H78540
Twin Seal Electric Submersible Pump Packer..... 76
H68357, and
Models A and A-1 Extenda-Joint........................ 98
H78570
ElecPak Electric Submersible Pump Packer ........ 78
H79080, and
FLX Packoff Tubing Hanger ................................. 80
H68354
H68376
Telescoping Space-Out Joint (TSOJ) ................ 106
H79085
H68420,
L-10, R-10, L-316 and R-316 On-Off Sealing
H79101
Mudline Tubing Hanger....................................... 79
H79928
E Hydro-Trip Sub................................................ 111
H81920
Flow Coupling.................................................... 116
H68421, and
Connector Family.......................................... 100
H68437
H70001
Model A Full-Opening Parallel Flow Tube ....... 110
H70010
Model A Full-Opening Anchor Parallel
Flow Tube .................................................... 110
H70032
Parallel Head ....................................................... 73
H70202
F Parallel Locator Seal Nipple........................... 110
H70301
Model A Parallel Anchor Seal Nipple ............... 110
H70311
K Parallel Anchor Seal Nipple........................... 107
H70701
F Parallel Snap-Latch Seal Nipple .................... 110
H70703
S Snap-Latch Seal Nipple ................................. 107
v
Material Selection
Material Selection
Baker Hughes equipment is offered in various material conigurations
for a variety of well conditions. Baker Hughes employs leaders in the
ield of metallurgy and polymer chemistry to ensure superior material
recommendations are made to our customers.
„„Severely
corrosive CO2 and H2S–nickel alloys such as 825, 925 and
718 at strength levels of 110 ksi minimum yield strength and higher
„„Severely corrosive CO , H S and free sulfur–nickel alloys such as
2
2
625 Plus, 725 and, less frequently, C-276 at strength levels of 120 ksi
minimum yield strength and higher
For corrosive wells, Baker Hughes corrosion metallurgists and polymer
scientists are available to provide expert material recommendations. To
For equipment required to perform a temporary function and then
provide the most cost-effective recommendations, the well environment
allow quick removal by drilling or milling, an additional group of
data form has been developed to aid in gathering the necessary well data. materials is used:
„„Cast
The following alloys and groups of alloys are currently the most
common materials used for the construction of packers and
related equipment:
„„Standard,
non-corrosive service–low alloy steels (e.g. 4140) with
mechanical properties compatible with API P110 tubulars
„„Non-corrosive service containing H S–low alloy steels (e.g. NACE
2
MR0175 compliant 4140) with mechanical properties compatible
with API L80 tubulars
„„Corrosive CO service with little or no H S–Martensitic and PH
2
2
stainless steels (e.g. 9Cr, 13Cr, 17-4PH, alloy 450, Super 13Cr) with
mechanical properties that vary from 80 ksi to 110 ksi minimum yield
strength; the selection of the specific corrosion-resistant alloy(s)
depends on the environment (pH, chlorides, temperature, H2S, etc.,)
and strength requirements
iron
„„Reinforced
polymer-based composites
Besides the more common materials, Baker Hughes manufactures
packers and related equipment from other materials when raw material
availability, quantities, delivery schedules, etc., permit. Example alloys
include 316L austenitic, 22 Cr duplex, 25 Cr duplex, 25 Cr super duplex,
alloy 20Cb3, 28 Cr super austenitic, K-500 Monel, alloy 2025, alloy
2535, alloy 2550, alloy G-3 and others.
1
Material Selection
Elastomer Selection
Ideally, seal materials have high strength and resiliency, and remain
unaffected by thermal or chemical environments. However, there is no
single material that offers adequate levels of these characteristics for
all downhole applications. Effective sealing in downhole environments
often requires a combination of materials to form a seal system.
Several sets of identical seal systems can be combined to create a seal
stack with redundant seals. Choosing the optimum seal stack requires
knowledge of the application and downhole conditions.
V-ring seal stacks can tolerate movement while holding high
pressures, providing they are always contained within a sealbore.
Therefore, while holding differential pressure, they must remain in the
sealbore. Selecting the most appropriate seal stack can be simpliied
by referring to the seal stack service matrix shown below.
Bonded seals are used in applications that require seals to be
repeatedly inserted into and removed from the sealbore while holding
differential pressure. This action is known as unloading. Bonded seals
are composed of high-strength elastomers, usually nitrile or Viton™,
which have limited operational capabilities.
„„“What
Applications beyond the capabilities of bonded seals require more inert
elastomers. Generally, these premium elastomeric materials have lower
resistance to extrusion than nitrile or Viton* and require the protection
of a containment system to prevent failures. Sealing systems using
contained premium elastomers are offered as a chevron- or v-ring-type
seal stack.
Selecting the most appropriate seal stack can be simpliied by referring
to the seal stack service matrix shown below. For additional information
regarding packer to tubing seal systems, ask your Baker Hughes
representative for a copy of the following:
to Consider When Designing Downhole Seals,” reprinted from
World Oil magazine
„„“Factors and Conditions Which Cause Seal Assemblies Used in
Downhole Environments to Get Stuck,” Engineering Tech Data™
Paper Number CS007
„„“Metal-to-Metal Sealing in Hostile Environment Completion
Equipment,” Engineering Tech Data Paper Number CS002
SELECTION GUIDE
Packer-to-Tubing Packing Unit
Pressure Differential
Seal Type
Non-Unloading
Environmental Compatibility X
Temp. Range
Unloading
H2S
Oil Base
Completion
Light Brine
Completion
Bromide
Completion
High pH
Completion
pH > 10
0-149
NO
OK
OK
CaBr2 /NaBr2
OK to 250°F
NO
pH >10
0-93
NO
OK
OK
OK
ZnBr2
NO
OK to 250°F
pH <10
OK
OK
NO
OK
to 200°F
OK
OK
PSI
MPa
PSI
MPa
°F
°C
Nitrile
Chevron
10,000
68.9
NO
NO
32-300
70 Hard Nitrile
Bonded
5,000
34.4
5,000
34.4
32-200
90 Hard Nitrile
Bonded
10,000
68.9
5,000
34.4
32-300
0-149
NO
OK
95 Hard Viton
Bonded
10,000
68.9
5,000
34.4
32-250
0-121
5%
OK
Amine
Inhibitors
OK
to 200°F
CaBr2 /NaBr2
OK to 250°F
HN-Ryte™
10,000
68.9
NO
NO
32-350
0-177
2%
OK
OK
ZnBr2
NO
V-Ryte™
15,000
103.3
NO
NO
A-Ryte™
15,000
103.3
NO
NO
A-HEET™
15,000
103.3
NO
NO
™
15,000
103.3
NO
K-HEET™
15,000
103.3
NO
Seal-Ryte™
15,000
103.3
Seal-HEET™
15,000
103.3
K-Ryte
X
l
n
0-149
15%
0-204
5%
80-300
27-149
20%
80-450
27-232
7%
OK
OK
OK
NO
OK
to 200°F
NO
OK
OK
OK
OK
NO
OK
OK
OK
OK
80-300
27-149
20%
80-450
27-232
15%
NO
100-450
38-232
7%
OK
OK
OK
OK
OK
NO
100-550
38-288
n
OK
OK
OK
OK
OK
NO
NO
40-450
4-232
7%
OK
OK
OK
OK
OK
NO
NO
40-450
4-232
n
OK
OK
OK
OK
OK
R-Ryte™
10,000
68.9
NO
NO
325-450 l
163-232
7%
OK
OK
OK
OK
OK
Molyglass
10,000
68.9
NO
NO
125-300
52-149
15%
OK
OK
OK
OK
OK
Explosive decompression is chemical and mechanical in nature related to solubility of gas in elastomer and strength of that elastomer. Under rapid decompression,
the elastomeric seals in these units may be susceptible to explosive decompression, however, explosive decompression does not occur while seals are in service.
Refer to Baker Hughes' packer systems technical manual, Unit No. 8218-3, for complete temperature range information.
There are no known H2S limitations below 500°F (260°C).
*Viton is a registered trademark of Dupont.
2
32-300
32-400
Material Selection
InQuest TubeMove 2.0
The InQuest TubeMove™ program is a user-friendly, eficient means of producing tubing movement calculation reports.
The software performs a series of calculations that allow the user to determine the magnitude of forces, stresses, and changes in length of
tubulars suspended in wells. Advantages of using the program stem from the ability to properly design a completion using the appropriate
Baker Hughes equipment. The program enables the user to select the method of setting the packer, pick between single or dual string
completions, import survey data, and generate three dimensional representations of the well.
Version 2.0 of Tubemove gives the ability to export the result from different scenarios and plot into approved packer envelopes using the new
InQuest Sentry program. There are also new 3D graphics and an updated calculation package leveraging the most recent industry research
including enhanced buckling calculations and the ability to incorporate friction factors.
InQuest TubeMove is a proprietary program based on SPE #5143, entitled “Movements, Forces and Stresses Associated with Combination Tubing
Strings Sealed in Packers” by Hammer Lindl, and on SPE #178-PA “Helical Buckling of Tubing Sealed in Packer” by Lubinski, Althouse, and Logan.
Contact your local Baker Hughes representative for information.
3
Material Selection
4
Material Selection
Well Environment Data for
Material Recommendations
Date:
Requestor:
Phone:
Fax:
Customer:
Well Location/Name:
r
Well Type:
Gas
r
Oil
r
Injection/Disposal X
r
Casing/Tubing Selections:
(e.g., L80/13 Cr) Coated
Casing OD:
Casing Wt:
Casing Grade:
Tubing OD:
Tubing Wt:
Tubing Grade:
r
r
Circle or Underline all bold items in parenthesis to indicate units of measure
Depth (ft, m)
Applicable Equipment Type
Service Life (yrs, mo, days)
Packer:
SSSV:
BFC:
Liner Hanger:
Other:
Downhole Conditions
Location
Max Temperature
Min Temperature
Max Pressure
@ Reservoir
(°F,°C)
(°F,°C)
(psi, KPa)
@ Wellhead
(°F,°C)
(°F,°C)
(psi, KPa)
(ft, m)
Reservoir Depth:
Gas Phase CO2 @ (reservoir or WH):
(psia, mole%, ppm)
Gas Phase H2S @ (reservoir or WH):
(psia, mole%, ppm)
Field Design (max) Water Content:
(bbl/MMSCF, m3/m3)
Field design Water Cut:
(%)
Field design (max) Chlorides:
(ppm, mg/l)
Bicarbonate Ion Concentration:
(ppm, mg/l)
Organic Acid Concentration:
(ppm, mg/l)
Production Inhibitor: (continuous, batch, none)
Annulus/completion luid:
Inhibitor type:
(e.g., CaCl)
Inhibitor/type:
(e.g., amine)
/
Other luid exposure / concentration / time:
(e.g., mud acid, 15% HCl, xylene, toluene, methanol, caustic, >9 pH mud, scale inhibitor, etc)
Note: Request copies of water and gas analysis reports and attach to this form.
X
For injection and disposal wells, list all liquids and gasses injected. If well will initially be used as a producer, please ill out two forms.
Oxygen ppb is critical for injection well.
5
Packer Performance
Packer Performance Definition
The system, known as PERFORM™, is used to validate permanent
and retrievable packers are compatible with the demands of today's
critical completions. Ensuring all load combinations fall inside the
region formed by the curves conirms that the equipment is adequate
for the combined loading conditions. This area is called the “safe
performance envelope” In those instances where one or more sets
of loading conditions fall outside the safe performance envelope, a
detailed evaluation of all aspects of the proposed completion system
Baker Hughes has developed the industry's irst means of describing a
is required to upgrade its performance. Some conditions outside the
packer's performance capabilities, under all possible loading conditions. safe performance envelope adversely affect the packer’s ability to
The analytical system combines computer modeling, sophisticated
maintain its sealing integrity. Others may prevent the packer
numerical stimulation techniques, including inite element analysis,
from functioning as designed, while retaining pressure integrity.
exhaustive laboratory testing, and ield veriication. To apply this
For more information regarding PERFORM envelopes, contact your
technology, a graphical solution is used to provide an accurate and
local Baker Hughes Representative.
useful deinition of a packer's safe operating region.
The successful performance of any packer includes recognizing that
the combined effects of varying differential pressure or applied forces,
cannot be considered independently. Rating a production packer in
terms of differential pressure alone does not suficiently describe the
packer's performance limits. To accurately measure and compare the
performance of various packers, an understanding of the simultaneous
effects of differential pressure and axial loading is required.
P E R F O R M TM E n v e l o p e
Applied Axial Load
Tension
Safe
Operating
Area
0
Set-Down
BAK
UG
ER H
H E S Above
0
Differential Pressure
PERFORM ™ Permanent Packer Rating Envelope
6
Below
Single Zone
Production and Injection Completions
Tubing
In low-pressure lowing or injection wells completed in shallow zones,
economical tension-set packers are typically used for the completion.
Various mechanical-set styles are available; this normally includes a single
packing element system without a bypass or unloader. These styles offer
the simplest means of isolating the casing annulus. Packers, such as the
AD-1™ packer, are tension-set by necessity, because their shallow-zone
applications lack suficient set-down weight to adequately pack-off the
element system.
A common single-zone well completion, at moderate depths and pressures,
will require a compression-set packer. It will include features suited for
the well's current lowing condition and future pumping treatments of that
zone. The R-3™ packer has been used widely as a standard-production
packer. This type of packer is limited to moderate treating pressures
because of their packer-to-tubing tension loads, which can be seen during
treating procedures. In higher-bottomhole- temperature wells, effects of
treating pressures and cooling of the tubing string must be evaluated to
ensure the tension forces do not force the internal bypass open.
R-3™ Double Grip
Retrievable Packer
When high packer-to-tubing forces, during treatments, are anticipated
or for injection completions, mechanical-set packers are available which
mechanically lock the internal bypass closed until the packer is released.
Pup Joint
Bottom No-Go
Tubing Nipple
Wireline Entry Guide
7
Single Zone
Fracturing and Stimulation Completion
Fracturing and stimulation operations, carried out through the tubing
string, impose the highest demands on retrievable packers. Besides
wellbore conditions, these operations can create tremendous dynamic
loads on the sealing system and mechanics of the packer. The tool is often
subjected to high-bottomhole-setting temperatures and pressures. Hightensile loads are transmitted to the packer as the tubing string is cooled
through the duration of pumping operations. The packer is also subjected
to extreme reversals of pressure differential. It must be able to anchor the
tubing against the changing tensile loads and maintain a seal throughout
the operation and the well’s return to production. The HORNET ™ packer
was designed speciically to address such conditions. It is often run with
the L-10™ on/off connector to control circulation of alternate luids, while
permitting the packer to remain set as the tubing is disconnected for
circulation and then re-latched. The HORNET is versatile in its deployment
method since it can be run on either tubing or wireline.
L-10™ On/Off
Connector
HORNET™
8
In the most extreme conditions of pressure, temperature, and packer-totubing loads, the HORNET packer sets the standard for high-performance
reliability; can be used in tension, compression, and neutral landing
conditions. The L-10 on/off tubing seal connector is often included in these
completions to permit retrieval of the tubing when removal of the packer
is not required.
Single Zone
Perforating, Treating and Fracturing Through
Casing Completion
Perforating underbalance, treating, or fracturing through the casing are
common procedures for new completions. Although various methods
address this need, it is often beneicial to use a wireline-set retrievable
packer as a means of temporary plugging the well. This enables the well
to resume production quickly following the operation. The alternative is to
snub tubing in the hole or kill the well.
Blanking Plug
L-10™ On/Off Tool
The WL™ packer addresses such applications and has features speciically
designed to help manage these problems. It is run with the L-10™ on/off
connector as its companion tool. Typical installations involve wireline
deployment, permitting setting in pressurized wells. With a wirelineretrievable plug installed in the L-10 seal nipple proile before deployment,
the packer serves as a temporary bridge plug. When the wirelineretrievable plug is installed above the packer, any sand can be completely
washed from the plug’s locking mechanism just before attaching the
tubing string to the seal nipple. When the plug is removed well production
is restored.
WL™ Packer
9
Single Zone
Hydraulic-Set Packer Completion
When it’s desirable to lange up the wellhead before setting the packer
or where there is concern about the ability to get rotation to the packer,
hydraulic-set packers may be used to complete the well. Completions
with hydraulic-set packers require a means of temporarily plugging the
tubing, typically a wireline-entry guide with pump-out plug, ball-seat sub,
or a proile-landing nipple for use with a wireline-retrievable plug. Pump
pressure applied down the tubing string provides actuation of the packer's
setting mechanism.
These packers can be either permanent or retrievable. The retrievable
versions normally include a shear release, requiring only straight pull on
the packer. The completion design must consider potential forces acting
on the shear release, particularly when HS™ hydraulic-set retrievable
packer well treatments are expected.
HS™ Hydraulic-Set
Retrievable Packer
Pup Joint
Bottom No-Go
Tubing Nipple
Wireline Entry Guide
10
Single Zone
Sealbore Packer Completion
The single-string sealbore packer is a common and simple means of
completion and offers built-in versatility and lexibility. Sealbore packers,
like the Signature DB™, FB-1™ permanent packers or SC-2™ retrievable
packers, permit large full-bore low passages.
Safety Valve
CMD Sliding Sleeve
™
G-22™ Locator
Seal Assembly
Signature DB Retainer
Production Packer
The tubing string can be positioned into the sealbore packer in two ways:
a locator tubing seal or anchor tubing seal assembly. The locator tubing
seal provides a high-pressure seal between the packer and tubing and
allows movement of the seals during well operations. The inclusion of
extra tubing-seal units below a locator, as shown in the accompanying
hookup drawing, compensate for tubing movement by traveling through
the packer bore and the sealbore extension. The required length of the
sealbore extension can be calculated using the InQuest TUBEMOVE™
program and consideration of all activities throughout the life of the well.
Alternatively, an anchor tubing-seal assembly can be used in place of the
locator. The anchor attaches the tubing string to the packer, restricting
motion of the seals and transmitting tubing forces through the packer to
the casing. The anchor is released by right-hand rotation. The packer and
tailpipe assembly are run in and set either on wireline or tubing, with a
setting tool. Use of a blanking plug in the tailpipe controls the well and
allows installation or removal of tubing, eliminating possible formation
damage due to kill luids.
Both methods permit thru-tubing perforation, while pressure is maintained
for safety and langed up displacement of well luid through the sliding
sleeve. Pressure and temperature recording instruments can be set in the
lower seating nipple without restricting the low path, while protecting the
instruments from low turbulence and vibration. Flow couplings in this and
other completions are recommended based on individual conditions.
Sealbore Extension
Top No-Go Nipple
Perforated Pipe
Bottom No-Go Nipple
Wireline Entry Guide
11
Single Zone
DV Production Packer/
Plug Completion
L-10™ On/Off
Connector
Blanking Plug
L-10 On/Off
Connector
DV Production Packer
12
The L-10™ on/off connector, used with a DV™ production
packer, alleviates common problems associated with
using blanking plugs in the tailpipe of packers. A blanking
plug installed in the L-10 seal nipple proile converts a DV
production packer into a temporary bridge plug that is carried
in and set on electric line or drillpipe in a single run. The
system enables an operator to perforate and stimulate an
upper zone, while isolating a lower zone. The location of the
setting nipple prevents the packer tailpipe from being fouled
by gun debris, stimulation settlings, or ill from upper zones.
Sealbore packers used for workovers are often subject to
problems caused by debris settling in the packer and tailpipe
while the tubing is removed. If wireline-conveyed blanking
plugs have been used to control the well or to protect the
formation, recovery problems can be experienced due to
the debris on the plug. This results in lost productivity and
added costs involved with removing the ill above the plug
or extensive ishing operations to clear the wellbore. When
a workover is required, a blanking plug is placed in the
nipple proile of the L-10 to eliminate low before the tubing
is removed. When the tubing is run back into the well, the
sand can be washed away as the standard L-10 washover
shoe is engaged. This provides clear access to the blanking
plug, which can be removed by conventional methods.
Single Zone
Monobore Completion
A monobore is a specialized type of completion, often performed by using
a permanent packer and PBR-style hookup.
Safety Valve
Polished Bore
Receptacle
KC-22™ Anchor
Tubing Seal Nipple
Typically, a granite packer, which is a no-body-movement, hydraulic-set
permanent packer, is stabbed into a liner top. A NPR™ (no proile required)
production bridge plug is run in place or deployed on electric line, slickline,
or coiled tubing and set in the tubing string below the packer to provide
a plugging device for setting purposes. Using this coniguration enables
completion of the well with a minimally compromised ID, due to the
elimination of restrictions in the production string, speciically the nipple
proiles. The safety valve, if present, is the only restriction in the system.
The combination of a hydraulic-set permanent packer, with a polishedbore receptacle (PBR), is a lexible and common well completion method.
It’s used when a maximum ID is required to maintain high- production or
treating-pump rates. This completion design allows the entire completion
to be run in one trip, while permitting displacement of wellbore luids and
langed-up packer setting.
The permanent packer features an enlarged alternate-upper sealbore
above the packer. An anchor tubing seal assembly is latched into the
alternate bore with a PBR extending above it. Thus, low area, equivalent
to the packer's lower bore, can be maintained. The PBR allows for extreme
tubing movement during well operations. Due to the demanding conditions
in which they are often run, success with these types of completions
depends on accurately calculating the forces that might act on the tubing,
packer, and seal assembly using InQuest TUBEMOVE™.
Granite or Premier
Production Packer
Tieback Seals
(Existing Liner Top)
13
Multiple Zone
Multiple-Zone Plug-Back
Option Completion
KC-22™ Anchor
Tubing Seal Nipple
Retainer Production Packer
Millout Extension
Top No-Go Tubing Nipple
Wireline Entry Guide
Retainer Production Packer
Millout Extension
Bottom No-Go Tubing Nipple
Wireline Entry Guide
14
Multizone wells can be completed for a minimum initial cost and have
built-in lexibility. During the initial completion phase, both packers are
installed above the target zones. The lower zone is then perforated and
the well is put on production. Later, without the use of a workover rig,
the lower zone can be plugged off and the upper zone perforated and
produced. The zones can also be commingled at any time during the life
of the well.
Multiple Zone
Single-String Selective Completion
Top No-Go Nipple
G-22™ Locator
Seal Assembly
Retainer Production Packer
The single-string selective completion permits selective production,
testing, stimulation, and isolation of various zones. This example shows a
completion using permanent-or retrievable-sealbore packers and locator
tubing-seal assemblies. The use of sealbore packers is one method which
allows perforating and testing of each zone as completion of the well
progresses from the bottom up. Selectivity is accomplished by opening
and closing the sliding sleeve between the packers. Blast joints located
adjacent to producing zones resist the erosive forces of produced luids.
Sealbore Extension
CMD™ Sliding Sleeve
Blast Joint
G-22 Locator
Seal Assembly
Retainer Production Packer
Sealbore Extension
CMD Sliding Sleeve
Blast Joint
G-22 Locator Seal Assembly
Retainer Production Packer
Sealbore Extension
Bottom No-Go Nipple
Wireline Entry Guide
15
Multiple Zone
One-Trip Single-String Selective Completion
CMD™ Sliding Sleeve
HS™ Retrievable
Hydraulic Set Packer
CMD Sliding Sleeve
Blast Joint
HS Retrievable
Hydraulic Set Packer
CMD Sliding Sleeve
Blast Joint
HS Retrievable
Hydraulic Set Packer
Bottom No-Go Nipple
Wireline Entry Guide
16
This single-string selective completion permits a single-trip langed-up
completion, using hydraulic-set tubing retrievable packers with sliding
sleeves. The completion also allows commingling of zones or separate
production, isolation, testing, or individual stimulation of zones. Sliding
sleeves between the packers make this range of selections possible.
If selectively set hydraulic packers are used, each packer can be
independently set and tested to ensure proper isolation between zones.
Multiple Zone
High-Pressure Dual-String Completion
Safety Valves
Completing high-pressure, multizone wells normally requires permanent
packers. Lower packers isolate the lower payzone, with production
directed through the packer's seal assembly and out through the longstring side of a parallel low tube. Flow from the upper zone is produced
through the bore of upper packers, directed into the short-string bore of
the Model A parallel-low tube. This installation requires an alternate
upper sealbore in the top packer to provide suficient diameter for the
dual-low paths, while also providing a seal area to isolate upper-zone
pressure at the packer.
Parallel Flow Tube
Locator Seal Assembly
Retainer Production Packer
Blast Joint
Locator Seal Assembly
Retainer Production Packer
Millout Extension
Bottom No-Go
Tubing Nipple
Wireline Entry Guide
17
Multiple Zone
One-Trip Dual-String Completion
Safety Valve
Safety Valve
Scoophead
GT™ Hydraulic Set
Dual Packer
Bottom No-Go
Tubing Nipple
Blast Joint
CMD™ Sliding Sleeve
HS™ Single String Retrievable
Hydraulic Set Packer
Bottom No-Go
Tubing Nipple
E™ Hydraulic-Trip
Pressure Sub
Wireline Entry Guide
18
Dual-zone completions can be designed for one-trip installation. Hydraulicset packers permit langed-up setting, eliminating the need for wireline.
Tubing nipples positioned below each packer provide the temporary
plugging required to set the packer or as required through the life of
the well. A sliding sleeve, positioned on the long string above the lower
packer, enables circulation or spotting of luids for upper-zone treatment
or production of the upper zone through the long string. As required in
offshore completions, subsurface safety valves installed on both strings
above the dual packer provide automatic shut-in if there is damage to the
tree or tubing strings above the packer. Moreover, this entire completion
system can be recovered in one trip.
Multiple Zone
One-Trip Dual-String Selective Completion
CMD™ Sliding Sleeve
GT™ Hydraulic Set
Dual Packer
Telescoping Swivel Sub
CMD Sliding Sleeve
Multizone completions can be designed for lexibility and economy. Dual
and single-string hydraulic-set retrievable packers can be set after the tree
is installed. Multiple payzones can be perforated in the initial completion
procedures and isolated when required without future rig intervention.
Sliding sleeves can be opened to produce from either tubing string,
between the dual packers. A telescoping-swivel sub is positioned below
the upper-dual packer on the short string to accommodate the run-in and
make-up procedures. Landing nipples positioned below the lower-dual
packer and lower single-string packer provide the temporary plugging
required during packer-setting procedures. This type of completion
coniguration offers long-term lexibility for changing well conditions,
while providing a completely retrievable completion system.
Blast Joint
GT Hydraulic Set
Dual Packer
Bottom No-Go
Tubing Nipple
Blast Joint
CMD Sliding Sleeve
HS™ Single String Retrievable
Hydraulic Set Packer
Blast Joint
CMD Sliding Sleeve
HS™ Single String Retrievable
Hydraulic Set Packer
Bottom No-Go
Tubing Nipple
Wireline Entry Guide
19
Deepwater
Deepwater Completion
Safety Valve
Seating Nipple
For deepwater completions, it is beneicial to set packers without the
requirement of intervention. Deepwater completions are considered to be
wells completed in 1,000 or more feet of water. The Premier removable
packer has been developed by merging hydraulic and hydrostatic
technologies into a design platform that reduces rig time and minimizes
the risk associated with standard well setting methods.
The Striker™ interventionless packer-setting system is for interventionless
actuation of the Premier™ packer. The proven Striker system is a device
that generates packer setting force from hydrostatic well pressure. As a
secondary or contingent setting method, this packer can also be set by
hydraulic pressure.
The Striker module design originated from the innovative and successful
SB-3H™ hydrostatic/hydraulic retainer production packer. Removal on the
production string is accomplished by cutting the mandrel with a chemical
or mechanical cutting tool. The Premier system offers high-performance
and multiple removal options for high-cost interventionless completions.
Premier™ Packer with Striker™ Module
Seating Nipple
Wireline Entry Guide
20
Deepwater
Extended-Reach Completion
Deepwater completions are considered to be those wells completed in
1,000 ft of water or deeper. Technology in this ield is growing at a rapid
pace in an effort to reach production quicker and reduce overall costs.
The example below of an extended-reach, highly deviated, gravel-packed,
completion features some of Baker Hughes' advanced technologies.
Safety Valve
After this well was gravel packed, the upper completion was run in
and set without the need of further intervention. The upper completion,
consisting of the SB-3H™ packer and polished-bore receptacle seal
assembly, was run and stung into the gravel-pack packer. After space
out, the packer was activated by applying hydraulic pressure to the well,
without the use of a plug in the tubing. A Baker Hughes luid-loss-control
valve was run below the gravel-pack packer, protecting the formation.
The valve was opened by additional cycles of applied hydraulic pressure
through the tubing, thereby completing the well without any intervention.
The SB-3H packer has been developed by merging hydraulic and hydrostatic
technologies into a design platform that reduces rig time and minimizes the
risk associated with standard well intervention setting methods.
Polished Bore Receptacle
SB-3H™ Packer
Top No-Go Tubing Nipple
Non-Sealing PBR with Tubing Seal Anchor
Sealbore Packer and Gravel Pack Completion
Fluid Loss Control Valve
21
Deepwater
Optimized TLP Deepwater Completion
Control Line Orientation Collar
Deepwater completions require many special considerations, including
the major economic impact of the size of offshore tension-leg platforms
(TLPs). The major factor inluencing the size of the TLP is the weight of the
equipment it must support. The weight of the production tubing, which
becomes greater as drilling depth increases, led Baker Hughes to develop
the mud-line tubing hanger (MLTH) to suspend the production tubing in
dual-riser TLP applications for Gulf Coast operators.
Mud Line Tubing Hanger (MLTH)
As shown in this illustration, the MLTH affords multiple control and
instrumentation line bypass for safety valves and gauges. Additional
features, such as the ability to displace nitrogen into the annulus from the
MLTH to the surface for thermal insulation purposes.
To streamline well completion activities and greatly reduce rig-time risk
and costs, Baker Hughes' Premier™ with Striker can be used for the upper
completion of this well. After displacing the well to completion luid, the
gravel pack was isolated with a single-string retrievable packer, which
was set without intervention by wireline or coiled tubing.
Safety Valve
Gauge Carrier
Top No-Go Tubing Nipple
Premier™ Packer with Striker
Bottom No-Go Tubing Nipple
Stinger
Sealbore Packer and Gravel Pack Completion
22
Deepwater
Single Riser TLP Deepwater Completion
The desire to minimize cost and add functionality to a tubing hanger
system led Baker Hughes to develop the system shown below.
The pack-off tubing hanger (POTH) allows an operator to use only one
riser to the TLP, while maintaining dual barriers and allowing downhole
monitoring, chemical injection, safety valves, and improving workover
functionality. The control lines and TEC wire pass through the POTH
without connections to minimize leak paths. Upper-and lower-annulus
pressure and communication are monitored and controlled with a
specialized T-Series™ safety valve. A special NM punch-release anchor,
with a control-line-severing feature, facilitates removing the upper-tubing
string without cutting or rotation. The POTH assembly combines these
functions into a single, safe, reliable assembly that allows the customer's
TLP to use a single riser, saving tens of thousands of pounds in weight and
many hours of rigtime and capital expenditure.
FLX™ Pack-Off Tubing Hanger
Communication Sleeve/Punch Release Nipple
Chemical Injection Valve
Flow Coupling
Safety Valve
Flow Coupling
Pressure Gauge
NM Punch Release Anchor
Premier™ Packer with Striker
Bottom No-Go Tubing Nipple
Perforated Joint
Sealbore Packer
23
High-Pressure/
H i g h -Te m p e r a t u r e
High-Pressure/
High-Temperature Completion
Safety Valve
Top No-Go
Tubing Nipple
L-36 Locator
Seal Assembly
FB-3™ Retainer
Production Packer
Sealbore Extension
Flow Coupling
Top No-Go
Tubing Nipple
Bottom No-Go
Tubing Nipple
Wireline Entry Guide
24
Wells above 300°F (149°C) and 10,000 psi (68 948 kPa) differential
pressure are generally considered hostile environment or high-pressure/
high-temperature (HP/HT), completions. Baker Hughes offers a host of
equipment speciically designed for use in hostile-environment wells.
At irst glance, the hookup shown appears the same as a simple singlezone completion. However, the equipment is speciically designed to
handle the extreme conditions of an HP/HT well. One-trip hydraulic-set
systems and various tubing-release systems are also available in
HP/HT trim.
Besides packers, Baker Hughes offers a full complement of HP/HT
completion equipment, including safety valves and low-control equipment
rated to 15,000 psi (103 421 kPa) at 450°F (232°C), as well as liner
hangers and liner-top packers rated in excess of 10,000 psi (68 948 kPa)
at 350°F (177°C). Special order packers have been used in applications
requiring 20,000 psi (137 895 kPa) differential pressure capability at the
packer. Contact your Baker Hughes representative for further information
about HP/HT products.
Thermal
Single-Zone Thermal Completion
Thermal completions pose especially dificult conditions for production
packers. Besides the obvious high temperatures, the tool is exposed to
large and sometimes frequent temperature luctuations. To further impede
performance, scale and other deposits form due to the boiling of luids
around the packer. Another consideration is thermal applications, which
are often economically marginal and technically challenging.
The MJS™ retrievable packer is a rotationally set packer that can be set
in deep or shallow wells. Its double-grip design makes it ideal for use
in steam injection, huff and puff, or geothermal wells when differential
pressures from above and below are anticipated. The packer's integral
expansion joint provides for tubing movement during steaming and
producing cycles and eliminates the need for additional equipment above
the packer. For insulated tubing applications, the packer is available
with an insulated mandrel to reduce heat loss. During expansion and
contraction, scraper rings protect the internal seal system from deposits
that build up on the mandrel due to local boiling. An outer element system
above the slips protects the releasing system from debris.
MJS Thermal Packer with
Integral Expansion Joint
Wireline Entry Guide
25
C02 Injection
and Waterflood
CO2 Injection And Waterflood Completion
The characteristics of these applications prove valuable when it is
preferable to control the charged-formation pressures without requiring
killing the well. Corrosion and scale accumulation should also be
considered when specifying downhole tools. The economical A-3™ or
large-bore AL-2™ LOK-SET™ is selected for such applications because they
allow setting the packer in relatively shallow wells and leaving the tubing
in tension, neutral, or compression conditions.
L-316 On-Off
Sealing Connector
B Two-Way Downhole
Shut-Off Valve
A-3 LOK-SET
Retrievable Packer
Wireline Entry Guide
26
The B™ two-way downhole shutoff valve can be run directly above the
LOK-SET packer to allow the packer to serve as a bridge plug that will
control pressures during tubing removal and re-installation. The B’s
mechanically actuated ball valve provides an alternative to relying on
proper setting of a wireline retrievable plug, as scale often interferes with
its setting, retrieving and sealing reliability. The valve also eliminates
potential damage associated with wireline running in expensive, internally
plastic-coated tubing.
The L-316 on-off connector is typically run directly above the shutoff valve.
The left-hand torque required to disconnect the on-off connector also
serves to close the shutoff valve with one-half turn left-hand rotation.
When the tubing is re-engaged to the seal nipple, the shutoff valve is
opened with one-half right-hand rotation at the tool.
Waterflood
Multizone Waterflood Injector Completion
Tandem Tension Packer
Applications for waterlood completions requiring multizone injection can
be economically addressed with single-string packers. Downhole low
regulators, installed in side-pocket mandrels, provide control of volumes
directed to the upper zones. The proile in the lower-nipple proile below
the lower packer can accommodate an in-line low regulator to control
injection into the lower zone.
Side Pocket Mandrel with
Downhole Flow Regulator
Tandem Tension Packer
Side Pocket Mandrel with
Downhole Flow Regulator
A-3™ LOK-SET™ Retrievable Packer
Downhole Flow Regulator
Wireline Entry Guide
27
Electric Submersible Pump
Single-Zone ESP Completion
In conventional electric submersible pump (ESP) applications,
the hydraulic-set ESP packer performs the function of tubing hanger and
well-control device. If gas is present during production, a Model AGV or
VR gas-vent valve may be mounted in a vent port in the packer to reduce
the volume of free gas produced through the pump, which increases
eficiency. Circulation above the packer is accomplished through a sliding
sleeve. In many applications, a standing valve is placed above the pump
to prevent backlow when the pump is turned off, preventing possible
damage to the pump when the motor is restarted.
Gas Vent
Elecpak ESP Packer
Top No-Go Tubing Nipple
Centrilift ESP
28
ElecPak™ is designed to facilitate the use of an electric submersible pump
(ESP). The packer allows for the incorporation of an integral electric cable
penetrator or a feed-through drop-in penetrator system. The innovative
design provides a multiple-port coniguration for venting annular pressure,
luid injection, and instrument wire access.
Electric Submersible Pump
Single-Zone ESP With Wireline Access
Safety Valve
A common ESP pump completion scenario includes a formation that lows
naturally, but one that could be damaged by kill-weight luids during a
workover. The Y-Block in the production string allows wireline access
below the pump and motor assembly through the tubing for logging and
monitoring purposes. In the event of a workover, a wireline- blanking plug
can be set below the sealbore packer to maintain well control, while the
upper section of the completion is removed from the well.
The production normally lows from the producing formation below the
seal-bore packer, through the sliding sleeve, into the annulus and pump
inlet. If desired, the sleeve can be closed to permit direct production from
the formation to the surface, bypassing the pump.
Packer
Top No-Go Tubing Nipple
If it is desired to monitor the well continuously; optional feed-through
passages in the ESP packer can facilitate running of downhole gauges.
In applications where the casing design will not permit the use of bypass
tubing alongside the pump assembly, a RCV (reservoir control valve) can
be placed above the sealbore packer to maintain well control during
workovers without the need of wireline intervention. These products are
described in the Baker Hughes low control product catalog.
Y-Block
Top No-Go Tubing Nipple
Centrilift ESP
CMD™ Sliding Sleeve
Top No-Go Tubing Nipple
Locator Seal Assembly
Sealbore Packer
Millout Extension
Top No-Go Tubing Nipple
Bottom No-Go Tubing Nipple
Wireline Entry Guide
29
Electric Submersible Pump
Intelligent Well System™
The following well has two zones produced by ESP. The lower zone
tends to generate excessive water when produced continuously and has
excellent oil reserves, but requires periodic shut-in to allow the water
inlow to subside. The objective is to maximize oil production, using realtime management of the lower zone. Previously, the lower zone has not
been produced due to the water coning problems.
The previous completion design did not have the space to install a Y-Block
to allow intervention for the manipulation of a conventional low-control
device. Therefore, the ability to periodically shut off the lower-zone
production without well intervention was needed.
ESP
HCM™ Hydraulic
Sliding Sleeve
Downhole Gauges
Elecpak™ Packer
30
This solution isolates the upper and lower zones with an ElecPak™ packer
and enables unrestricted production from the upper zone. A surfacecontrolled hydraulically operated sliding sleeve regulates lower-zone
inlow when reservoir conditions require it and eliminates the need for
intervention. Temperature and pressure sensors to monitor contribution
from the lower zone are incorporated.
Permanent Packer Systems
Permanent Packer Systems Introduction
The industry’s irst and inest Permanent Packer
The Baker Hughes D™ retainer production packer has been the industry standard for decades. The sealbore packer concept has enabled
Baker Hughes to record several industry irsts in “advancing reservoir performance.” Baker Hughes introduced the irst packer to hold pressure
from above and below; the irst packer to stay packed off without constant set-down weight or tension, and the irst packer to accommodate
tubing movement. The D retainer production packer made it possible to complete a well from two zones and was used in the irst dual completion.
The present Baker Hughes family of dependable permanent packers has been developed through years of experience. The Signature D and DB™
packers are the culmination of those years of experience and are the foundation of the permanent packer product line.
31
Permanent Packer Systems
PERMANENT PACKER SELECTION
Setting Method
Product
Family No.
Single Bore
Signature D
H43210 and H43211
x
x
D, DB
H41505, H41525
and H41513
x
x
DA, DAB
H41514, H41508,
H41526 and H41503
F-1, FB-1
H41306,H41308
andH41340
FA, FA-1,
FAB, FAB-1
H41309, H41307,
H41309 and H41341
Product Application
32
Alternate Bore
x
x
FB-3
H41350
x
H40906
x
SAB-3,
SABL-3
H40907,
H40908
SABL-4
H40921
SB-3H
H40932
x
Granite
H40934
x
Hydraulic
Hydrostatic
No Mandrel
Movement
x
x
x
SB-3
Wireline/
Hydraulic
Setting Tool
x
x
x
x
x
x
x
x
x
x
x
Permanent Packer Systems
Signature D and DB Retainer
Production Packers
Product Family Nos. H43210 and H43211
APPLICATION
The Signature D™ (H43210) and Signature DB™ (H43211) retainer production
permanent packers are among the most widely used, most versatile and
highest-performing production packers available. They’re also frequently used
as a permanent test packer or as a bridge plug.
Advantages
„„Designed
for ease of milling
„„Proven reliability
„„Greater resistance to premature impact setting
„„Two opposed sets of full-circle, full-strength slips ensure packer
will remain properly set
„„Packing element resists swab off and allows faster
running time
„„Unique interlocking expandable metal backup rings contact casing,
creating a positive barrier to packing element extrusion
„„Composed of material suitable for H S service
2
„„Big-bore version provides largest bore through any drillable packer
„„Incorporates smooth, continuous ID sealing bore
Additional Information
The Signature DB’s blank or threaded (box or pin) bottom guide distinguishes
it from the Signature D. The Signature DB guide can be threaded to accept a
mill-out extension, seal-bore extension, or tubing.
Production Packer
Product Family
Nos. H43210 and H43211
SPECIFICATION GUIDE
Casing
OD
in.
Packer
Weight
mm
(lb/ft)
Size
Range of Casing ID
in Which Packer May be Run
Min
Max
Max
Tool OD
Min Bore Thru
Seal Nipple
Packer
Diameter
Sealing Bore
for Seal Nipples
Accessory
Size
40–26
in.
mm
in.
mm
in.
mm
in.
mm
in.
mm
10.5–13.5
375–268
3.92
99.6
4.052
102.9
3.75
95.2
1.937
49.2
2.688
68.3
2.688
15.1–16.9
356–250
3.629
92.2
3.826
97.2
3.562
90.5
1.875
47.6
2.5
63.5
2.5
20–25
15–21.4
396–268
4.125
104.8
4.408
111.9
3.968
100.8
1.937
49.2
2.688
68.3
2.688
40–26
20–23
432–268
4.578
116.3
4.811
122.2
4.328
109.9
14–17
450–268
4.819
122.4
5.044
128.1
4.5
114.3
1.968
49.9
2.688
68.3
2.688
40–26
4-1/2
114.3
5
127.0
5-1/2
139.7
6-5/8
7
168.2
177.8
20–32
32–42.7
546–325
5.569
141.4
6.135
160.4
5.468
138.9
(80) 2.406
(81) 1.995
61.1
50.7
3.25
82.5
3.25
80–32 or
81–32
6-5/8
7
168.2
177.8
20
23–32
568–325
5.597
142.2
6.366
161.7
5.687
144.4
(80) 2.406
(81) 1.995
61.1
50.7
3.25
82.5
3.25
80–32 or
81–32
7
7-5/8
196.6
17–20
33.7–39
618–325
6.381
162.1
6.765
171.8
6.187
157.1
(80) 2.406 or
(81) 1.995
61.1
50.7
3.25
82.5
3.25
80–32 or
81–32
7
7-5/8
196.6
24–33.7
637–325
6.662
169.2
7.025
178.4
6.375
161.9
80) 2.406 or
(81) 1.995
61.1
50.7
3.25
82.5
3.25
80–32 or
81–32
9-5/8
244.5
36–53.5
812–325
8.405
213.5
9.001
228.6
8.125
206.4
2.406
61.1
3.25
82.5
3.25
80–32
33
Permanent Packer Systems
D and DB Retainer Production Packers
Product Family Nos. H41505, H41525 and H41513
APPLICATION
Baker Hughes’ high-performance and versatile D™ and DB™ retainer production
packers are considered industry standards among permanent production packers.
Advantages
„„Proven
reliability
design
„„Solid construction enables 50% faster run-in without fear of impact
damage or premature setting, making significant rig-time
savings possible
„„Two opposed sets of full-circle, full-strength slips ensure packer will
remain properly set
„„Packing element resists swab-off and packs off securely when packer
is set
„„Unique interlocking, expandable, metal backup rings contact casing,
creating a positive barrier to packing element extrusion
„„Aflas packing element available in select casing- weight ranges
„„Slim-line
Additional Information
The D and DB retainer production packers are also frequently used as a
permanent squeeze or testing packer or as a permanent or temporary bridge plug.
DB Retainer Production Packer
with B Guide for Mill-Out Extension
Product Family No. H41505
34
Permanent Packer Systems
SPECIFICATION GUIDE
D™ and DB™ Retainer Production Packer, Product Family Nos. H41505, H41525 and H41513
Packer X
Casing
Weight n
OD
in.
4-1/2
◆
mm
Size ▲
Max OD
lb/ft
17.0–18.9
15.1–17.0
in.
19–25 3.475
21–25 3.562
mm
88.2
90.4
11.6–15.1
22–19 3.593
10.5–13.5
23–26 3.750
2.500
63.5
91.2
1.968
49.9
95.2
2.688
68.2
114.3
9.5–11.6
24–19 3.812
96.8
32–26
18–21.4
5
127.0
32–25 3.968
100.7
32–19
11.5–13
34–26
23–26.8
4.250
107.9
34–19 4.250
107.9
42–26
20–23
139.7
2.688
68.2
2.500
63.5
49.9
2.688
68.2
2.500
63.5
1.968
2.688
4.328
49.9
49.9
68.2
109.9
42–19
1.968
49.9
44–26
2.688
68.2
1.968
49.9
14–17
4.500
114.3
44–19
24–32
1.968
1.968
34–25
5-1/2
Diameter of
Sealing Bore
in.
mm
81–32 5.350
135.8
3.250
82.5
82–32
20–32
6-5/8
168.2
5.468
138.8
82–26
84–32
20
5.687
53.60–57.10 64–30 4.937 125.40
81–32 5.350
68.2
3.250
82.5
144.4
84–26
38–46.4
2.688
2.688
68.2
3.000
76.2
135.8
3.250
82.5
2.688
68.2
3.250
82.5
2.688
68.2
3.250
82.5
3.250
82.5
2.688
68.2
3.250
82.5
3.250
82.5
2.688
68.2
3.250
82.5
2.688
68.2
3.250
82.5
2.688
68.2
82–32
32–42.7
5.468
138.8
82–26
7
177.8
84–32
23–32
5.687
144.4
84–26
20–29
86–32 5.875
149.2
88–32
17–20
6.187
157.1
88–26
45.3–51.2
86–32 5.875
149.2
88–32
33.7–39
7-5/8
193.6
6.187
157.1
88–26
92–32
24–33.7
6.375
161.9
92–26
88–32
7-3/4
196.9
46.1–48.6
6.187
88–26
157.1
Seal Assembly l
Min Bore
Thru Seals ‡
Size
in.
mm
20–25
1.865
47.3
21–19
20/40–19
40/80–26
41/81–26
21–19
20/40–19
40/80–26
41/81–26
20–25
21–19
20/40–19
40/80–26
41/81–26
20–25
21–19
20/40–19
40/80–26
41/81–26
21–19
20/40–19
40/80–26
41/81–26
21–19
20/40–19
60/80–32
61/81–32
60/80–32
61/81–32
40/80–26
41/81–26
60/80–32
61/81–32
40/80–26
41/81–26
42/62–30
40/60–30
60/80–32
61/81–32
60/80–32
61/81–32
40/80–26
41/81–26
60/80–32
61/81–32
40/80–26
41/81–26
60/80–32
61/81–32
60/80–32
61/81–32
40/80–26
41/81–26
60/80–32
61/81–32
60/80–32
61/81–32
40/80–26
41/81–26
60/80–32
61/81–32
40/80–26
41/81–26
60/80–32
61/81–32
40/80–26
41/81–26
1.312
.984
1.968
1.750
1.312
.984
1.968
1.750
1.865
1.312
.984
1.968
1.750
1.865
1.312
.984
1.968
1.750
1.312
.984
1.968
1.750
1.312
.984
2.406
1.990
2.406
1.990
1.968
1.750
2.406
1.990
1.968
1.750
2.375
1.970
2.406
1.990
2.406
1.990
1.968
1.750
2.406
1.990
1.968
1.750
2.406
1.990
2.406
1.990
1.968
1.750
2.406
1.990
2.406
1.990
1.968
1.750
2.406
1.990
1.968
1.750
2.406
1.990
1.968
1.750
33.3
24.9
49.9
44.4
33.3
24.9
49.9
44.4
47.3
33.3
24.9
49.9
44.4
47.3
33.3
24.9
49.9
44.4
33.3
24.9
49.9
44.4
33.3
24.9
61.1
50.5
61.1
50.5
49.9
44.4
61.1
50.5
49.9
44.4
60.3
50.0
61.1
50.5
61.1
50.5
49.9
44.4
61.1
50.5
49.9
44.4
61.1
50.5
61.1
50.5
49.9
44.4
61.1
50.5
61.1
50.5
49.9
44.4
61.1
50.5
49.9
44.4
61.1
50.5
49.9
44.4
Packer X
Casing
Weight n
OD
in.
mm
36–49
8-5/8
Size s
lb/ft
219.0
24–36
126–38
126–40
128–38
128–40
Max OD
in.
mm
7.125
180.9
7.500
190.5
8.125
206.3
194–47
9-5/8
244.4
36–53.5
194–40
194–32
194–47
9-7/8
250.1
62.8
194–40
8.125
206.3
194–32
212–47
60.7–79.2
10-3/4
⊕∆
9.000
⊕∆
l
n
▲
‡
◆
⊕
∆
101.6
82.5
4.750
120.6
4.000
101.6
3.250
82.5
4.750
120.6
192–47
82.5
4.750
120.6
190–47
191–47 or
192–47
214–32
3.250
82.5
80–32 or
81–32
220–47
4.750
120.6
190–47
191–47 or
192–47
220–32
3.250
82.5
80–32 or
81–32
230–60
6.000
152.4
190–60
4.750
120.6
190–47
191–47 or
192–47
230–32
3.250
82.5
80–32 or
81–32
240–60
6.000
152.4
190–60
212–32
298.4
3.250
9.437
239.7
10.437 265.1
42–60
230–47
11.562 293.6
339.7
48–72
X
4.000
3.250
273.0
61–102
13-3/8
120.6
228.6
214–47
⊕∆
4.750
Seal Assembly l
Min Bore
Size
Thru Seals ‡
in.
mm
120–38
2.468
62.6
80–40
2.985
75.8
120–38
2.468
62.6
80–40
2.985
75.8
192–47
3.875
98.4
190–47
3.000
76.2
191–47
2.500
63.5
80–40
2.985
75.8
60/80–32 2.406
61.1
61/81–32 1.990
50.5
192–47
3.875
98.4
190–47
3.000
76.2
191–47
2.500
63.5
80–40
2.985
75.8
60/80–32 2.406
61.1
61/81–32 1.990
50.5
3.000
76.2
190–47
63.5
191–47 or 2.500
80–32 or
81–32
32.75–60.7
11-3/4
Diameter of
Sealing Bore
in.
mm
3.875
98.4
4.000 101.6
3.875
98.4
4.000 101.6
240–47 12.000 304.8
4.750
120.6
240–32
3.250
82.5
190–47
191–47 or
192–47
80–32 or
81–32
3.875
98.4
2.406
61.1
1.990
50.5
3.000
2.500
3.875
2.406
1.990
3.000
2.500
3.875
2.406
1.990
76.2
63.5
98.4
61.1
50.5
76.2
63.5
98.4
61.1
50.5
4.875
3.000
2.500
3.875
2.406
1.990
123.8
76.2
63.5
98.4
61.1
50.5
4.875
3.000
2.500
3.875
123.8
76.2
63.5
98.4
2.406
61.1
For information on packer accessory sizes not found in the specification guide,
refer to Baker Hughes' packer systems technical manual or contact your
Baker Hughes representative
Tubing-seal assemblies, tubing-seal and spacer nipples
Includes some drillpipe and line-pipe weights
When proposed for use in other than the casing weight shown, contact your
Baker Hughes representative
Minimum bore applicable to standard G, E and K seal assemblies only; not
applicable to L, M and N seal assemblies with K-RYTE and R-RYTE seals which may
have reduced IDs
In 4-1/2-in. (114.3 mm) OD 11.6 lb/ft and heavier casing, the size 20 wireline
pressure setting assembly is too large and the size 10 assembly must be used.
In 4-1/2-in. (114.3 mm) 9.5 and 10.5 lb/ft casing, either the size 10 or 20 assembly
may be used.
Packers for sizes 10-3/4-in. (273.0 mm) and larger casing should be run and set
on a hydraulic setting tool. Product Family Nos. H41370, H41371, H741372, H41570,
H41572, H41574 or H43712
Packers for these sizes of casing are also available with other size seal bores on
special order.
35
Permanent Packer Systems
DA and DAB Retainer Production Packers
Product Family Nos. H41514, H41508, H41526 and H41503
APPLICATION
The DA™ retainer production packer provides all the versatility and highperformance characteristics of the D but with a larger sealing bore at the upper
end. It’s frequently used in complex multiple-string completions or when large
tubing is run and it is necessary to maintain clearance through the packer. The DA
is also used when the seal nipple is required to be compatible with the tubing ID.
Advantages
„„Slim-line
design
construction enables 50% faster run-in without fear of impact
damage or premature setting, making significant rig-time
savings possible
„„Two opposed sets of full-circle, full-strength slips ensure packer will
remain properly set
„„Packing element resists swab-off and packs off securely when packer
is set
„„Unique interlocking, expandable, metal backup rings contact casing,
creating a positive barrier to packing element extrusion
„„Typically has increased rating over similar size D or DB packer, when
accessory seals are landed in alternate bore
„„Aflas packing element is available in select casing weight ranges
„„Solid
Additional Information
The DAB™ packer’s threaded (box or pin) bottom guide differentiates it from the
DA. This DAB guide can be speciied for acceptance of a mill-out extension, sealbore extension or virtually any component desired. DA packers and their guides
can also be ordered separately by those interested in maximum
inventory lexibility.
Accessories
Packer plugging devices; packer sealing systems; packer extensions; parallel
low systems
DAB Retainer Production Packer
with B Guide for Mill-Out Extension
Product Family No. H41508
36
Permanent Packer Systems
SPECIFICATION GUIDE
DA™ Retainer Production Packer, Product Family Nos. H41503, H41508, H41514 and H41526
Weight l
OD
in.
4-1/2
mm
X
5-1/2
139.7
6-5/8
168.2
7
l
n
▲
‡
◆
▼
⊕
∆
177.8
7-5/8
193.6
7-3/4
196.9
8-5/8
219.0
9-5/8
244.4
9-7/8
X
114.3
250.1
Packer Sealing Bore
Packer ▲
Casing
Max OD
Size n
lb/ft
in.
mm
11.6–15.1
3.593
91.2
22DA25
9.5–11.6
3.812
96.8
24DA25
20–23
4.328
109.9
42DA32
4.500
114.3
44DA32
20–32
5.468
138.8
82DA40
20
5.687
144.4
84DA40
53.6–57.1
4.937
125.4
64DA36
32–42.7
5.468
138.8
82DA40
23–32
5.687
144.4
84DA40
17–20
6.187
157.1
88DA40
33.7–39
6.187
157.1
88DA40
24–33.7
6.375
161.9
92DA40
46.1–48.6
6.187
157.1
88DA40
36–49
7.125
180.9
126DA47
24–36
7.500
190.5
128DA47
36–53.5
8.125
206.3
194DA60
8.125
206.3
Seal Bore
in.
14–17
62.8
Lower ▼
Upper
194DA60
mm
Seal
Assembly
Size ◆
Min Bore
Thru Seals ∆
in.
mm
Seal Bore ‡
in.
mm
Min Bore
Thru Seals ∆
Seal
Assembly
Size ◆
in.
mm
1.312
or
0.984
33.3
or
24.9
2.500
63.5
20DA25
1.875
47.6
1.968
49.9
21–19
or
20/40–19
3.250
82.5
40DA/
SA32
2.500
63.5
2.688
68.2
40/80–26
1.968
49.9
4.000
101.6
80DA/
SA40
3.250
82.5
3.250
82.5
3.625
92.0
60DA36
or
61DA36
3.000
or
2.875
76.2
or
73.0
3.000
76.2
60/80–32
or
61/81–32
42/62–30
or
40/60–30
2.406
or
1.990
2.375
or
1.968
61.1
or
50.5
60.3
or
49.9
4.000
101.6
80DA/
SA40
3.250
82.5
3.250
82.5
60/80–32
or
61/81–32
2.406
or
1.990
61.1
or
50.5
4.000
101.6
80DA/
SA40
3.250
82.5
3.250
82.5
4.000
101.6
80DA/
SA40
3.250
82.5
3.250
82.5
60/80–32
or
61/81–32
60/80–32
or
61/81–32
2.406
or
1.990
2.406
or
1.990
61.1
or
50.5
61.1
or
50.5
4.750
120.6
82FA47 ⊕
or
81FA47
4.000
or
3.875
101.6
or
98.4
3.875
98.4
120–38
2.468
82.5
192–47
3.875
98.4
6.000
152.4
190DA60
4.875
123.8
4.750
120.6
190–47
3.000
76.2
191–47
2.500
63.5
192–47
3.875
98.4
190–47
3.000
76.2
191–47
2.500
63.5
6.000
152.4
190DA60
4.875
123.8
4.750
120.6
In 4-1/2-in. (114.3 mm) OD 11.6 lb and heavier casing the size 20 wireline pressure setting assembly is too large and the size 10 WLPSA MUST BE USED.
In 4-1/2-in. (114.3 mm) OD 9.5 and 10.5 casing, either the size 10 or 20 WLPSA may be used.
Includes some drillpipe and line pipe weights
When proposed for us in other than the casing-weight range shown contact your Baker Hughes representative
For information on packer or accessory sizes not found in this specification guide refer to Baker Hughes' packer systems technical manual or your
Baker Hughes representative
The maximum OD (including tolerance) of any part run through a production packer should be at least 1/16-in. (1.59 mm) smaller than the minimum bore through
the packer body. This may occassionally require that the coupling ODs be turned down.
Tubing seal assemblies, tubing seal and spacer nipples
Lower bore can be utilized as a seal bore. HOWEVER, strict dimensional analysis for compatibility of packer bore/seal accessory configuration is required to assure desired
performance. Compatibility is based on lower bore/seal nipple diametrical dimensions only. Final seating position of locating shoulder will vary between packer sizes. Anchor
mechanisms are not recommended.
Accessory size 82FA47 replaces both previous sizes 80FA47 and 120DA47
ID listed is for commonly used G-22™, E-22™ and K-22™ seal assemblies.
37
Permanent Packer Systems
DV Retainer Production Packer
Product Family No. H41534
APPLICATION
The DV™ packer combines the advantages of the proven D™ permanent packer with the lexibility of the
L-10™/R-10™ on-off sealing connector. By coupling these proven products, a lower zone can be isolated by
installing a plug in the proile of the seal nipple, enabling removal of the tubing string. NACE metallurgy and
non-elastomeric seal stacks can stand up to virtually all well conditions.
Advantages
„„Permits
blanking plug in seal nipple profile, improving debris removal from locks for reliable
plug retrieval
„„Disengagement of workstring by quarter turn provides minimal tubing manipulation, ideal for
deviated wells
„„Offers large IDs, particularly suited for small packer sizes
„„Maintains maximum packer-to-tubing tension ratings
„„Provides economical option for many HP/HT applications
L-10/R-10 On-Off Sealing Connector
Product Family Nos. H68420 and H68421
Additional Information
As with the conventional D packer, a prior gauge ring and junk basket are recommended to ensure
unrestricted deployment to setting depth. The DV packer can be run on either E-Line, using the
Baker Hughes E4™ setting tool or a workstring, using the J hydraulic-setting tool.
™
SPECIFICATION GUIDE
Casing
OD
Packer
Weight
Seal Nipple Min ID
Max OD
With Profile
Blank
Size
in.
4-1/2
5
mm
lb/ft
in.
mm
11.6–15.1
365–193
3.650
92.71
9.5–11.6
381–193
3.812
96.83
114.3
127.0
23.2
381–193
3.812
96.83
15–21.4
397–193
3.968
100.79
11.5–13
425–193
4.250
107.95
4.328
109.93
433–193
20–23
433–237
5-1/2
450–193
4.500
in.
mm
1.87
47.50
1.93
49.02
1.87
47.50
1.93
49.02
1.87
47.50
1.93
49.02
2.31
58.67
2.377
60.38
1.87
47.50
1.93
49.02
2.31
58.67
2.377
60.38
2.31
58.67
2.377
60.38
2.31
58.67
2.377
60.38
2.81
71.37
2.942
74.73
114.30
450–237
177.8
32–42.7
547–237
5.468
138.89
23–32
569–237
5.687
144.45
17–20
619–237
6.187
157.15
6.250
158.75
625–237
7-5/8
mm
139.7
14–17
7
in.
193.6
33.7–39
625–292
Note: Sizings for Aflas™ fitted assemblies might vary. Consult your Baker Hughes representative for verification.
DV Retainer Production Packer
Product Family No. H41534
38
Permanent Packer Systems
F-1 and FB-1 Retainer Production Packers
Product Family Nos. H41306, H41308 and H41340
APPLICATION
Baker Hughes F-1™ and FB-1™ retainer production packers are the big-bore versions of the high-performing
D retainer production packer. They feature the largest bore through any drillable packer. In the FB-1 version, a
mill-out extension, seal-bore extension or other component can be run below the packer.
Advantages
„„Slim-line
design
construction enables 50% faster run in without fear of impact damage or premature setting,
making significant rig-time savings possible
„„Two opposed sets of full-circle, full-strength slips ensure packer will remain properly set
„„Packing element resists swab off and packs off securely when packer is set
„„Unique interlocking, expandable, metal backup rings contact casing, creating a positive barrier to
packing element extrusion
„„Aflas packing element is available in select casing-weight ranges
„„Solid
Additional Information
F-1 guides can also be ordered separately by those interested in maximum inventory lexibility.
Additional Information
FB-1 Retainer Production Packer
with B Guide for Mill-Out Extension
Product Family No. H41308
Packer plugging devices; packer sealing systems; packer extensions
SPECIFICATION GUIDE
Casing
OD
X
l
n
▲
‡
◆
▼
⊕
in.
mm
4-1/2 n
114.3
5
127.0
5-1/2
139.7
6-5/8
168.2
7
177.8
7-5/8
193.6
7-3/4
196.9
9-5/8
244.4
9-7/8
13-3/8
250.1
339.7
Weight X
lb/ft
11.6–15.1
9.5–11.6
24.1
21.4–24.1
20–23
14–17
14
20-24
17
32–38
26–32
20–23
17–20
33.7–42.8
24–33.7
46.1–48.6
40–58.4
36–47
62.8
61–72
Packer ▲
Size ‡
22–23
24–23
22–23
24–23
43–30
45–30
47–30
83–40
85–40
83–40
85–40
87–40
89–40 ▼
89–40 ▼
91–40 ▼
89–40
192–60
194–60
192–60
240–93
in.
3.593
3.718
3.593
3.718
4.437
4.562
4.750
5.687
5.875
5.687
5.875
6.000
6.250
6.250
6.500
6.250
8.218
8.438
8.218
11.625
Seal Assembly l
Seal Bore ◆
Max OD
mm
91.2
94.4
91.2
94.4
112.7
115.8
120.6
144.4
149.2
144.4
149.2
152.4
158.7
158.7
165.1
158.7
208.4
214.3
208.4
295.2
Size
Min Bore Thru Seals ⊕
in.
mm
1.703
43.2
1.807
45.9
1.703
43.2
1.807
45.9
2.375
60.3
or
or
1.970
50.0
in.
mm
2.390
60.7
2.390
60.7
3.000
76.2
4.000
101.6
80–40
2.985
75.8
4.000
101.6
80–40
2.985
75.8
4.000
101.6
80–40
2.985
75.8
4.000
101.6
80–40
2.985
75.8
6.000
152.4
190–60
4.875
123.8
6.000
9.375
152.4
238.1
190–60
240–93
4.875
7.995
123.8
203.0
20–23
21–23
20–23
21–23
42/62–30
or
40/60–30
Includes some drillpipe and line pipe weights
Tubing-seal assemblies, tubing seal and spacer nipples
In 4-1/2-in. (114.3 mm) OD 11.6 lb and heavier casing the size 20 wireline pressure-setting assembly is too large and the size 10 WLPSA MUST BE USED. In 4-1/2-in.
(114.3 mm) OD 9.5 and 10.5 lb casing, either the size 10 or 20 WLPSA may be used.
For information on packer or accessory sizes not found in this specification guide refer to Baker Hughes' packer systems technical manual or your
Baker Hughes representative
When proposed for use in other than the casing-weight range shown contact your Baker Hughes representative
The maximum OD (including tolerance) of any part run through a production packer should be at least 1/16-in. (1.59 mm) smaller than the minimum bore through
the packer body. This may occasionally require that the coupling ODs be turned down.
Size 89–40 and 91–40 packers can be ordered with a lower pressure rating and an enlarged 4.400-in. (111.8 mm) inch seal-bore diameter.
ID listed is for commonly used G-22™ E-22™ seal assemblies.
Aflas is a registered trademark of Asahi Glass of Japan.
39
Permanent Packer Systems
FA, FAB, FA-1 and FAB-1
Retainer Production Packers
Product Family Nos. H41307, H41309 and H41341
APPLICATION
The FA-1™ retainer production packer is the big-bore version of the widely
used Baker Hughes DA packer. The FA-1 features an extended upper body that
accommodates a larger upper sealbore. This results in the largest possible ID
through the accessory and the packer. The FA-1 is available in smaller sizes (see
speciication guide), such as the FA™, which has the body-lock ring and setting
sleeve on the packer’s lower end.
The FAB™ and the FAB-1™ retainer production packers provide a threaded
bottom guide for attachment of a mill-out extension, seal-bore extension or
other component below the packer.
Advantages
„„Slim-line
design
construction enables 50% faster run-in without fear of impact
damage or premature setting, making significant rig-time
savings possible
„„Two opposed sets of full-circle, full-strength slips ensure packer will
remain properly set
„„Packing element resists swab-off and packs off securely when
packer is set
„„Unique interlocking, expandable, metal backup rings contact casing,
creating a positive barrier to packing element extrusion
„„Largest possible bore through packer with accessory seals in
alternate bore
„„Typically has rating greater than similar size F-1 or FB-1 when
accessory seals are landed in alternate bore
„„Aflas packing element is available in select casing weight ranges
„„Solid
Additional Information
FA-1 packers and their guides can also be ordered separately by those
interested in maximum inventory lexibility.
Additional Information
Packer plugging devices; packer sealing systems; packer extensions; parallel
low systems
Aflas is a registered trademark of Asahi Glass of Japan.
40
FA-1 Retainer Production Packer
with B Guide for Mill-Out Extension
Product Family No. H41309
Permanent Packer Systems
SPECIFICATION GUIDES
FA™ and FAB™ Retainer Production Packer, Product Family Nos. H41302 and H41305
Packer n
Casing
Weight X
OD
in.
2-3/8
2-7/8
mm
60.3
73.0
3-1/2
88.9
4
101.6
4-1/2 ∆
114.3
5
127.0
5-1/2
139.7
Size
l
Packer Sealing Bore
023FA12
028FA18
033FA20
035FA20
13FA25 ‡
15FA25 ‡
22FA30
in.
1.750
2.220
2.562
2.765
3.062
3.187
3.609
mm
44.4
56.3
65.0
70.2
77.7
80.9
91.6
9.5–11.6
24FA30
3.718
94.4
20–23.8
43FA36
in.
1.250
1.875
mm
31.7
47.6
2.062
52.3
030FA20
1.421
34.9
1.531
2.500
63.5
11FA25
1.875
47.6
1.875
Max OD
lb/ft
4.6–5.1
6.4–6.5
12.7–13.3
7.7–9.3
12.6–14
9.5–11.6
11.6–15.1
4.437
112.7
Lower ⊕
Upper
Seal
Assembly
Size ▼
020FA12
020FA18
Seal Bore
3.000
3.625
76.2
20FA/SA30
◆
020FA12
Min Bore
Thru Seals G
in.
mm
0.750
19.0
28.8
030FA15
1.000
25.4
47.6
11–18
1.000
25.4
21–23
or
20–23
1.807
or
1.703
45.9
or
43.2
42/62–30
2.375
60.3
40/60–30
1.970
50.0
Min Bore
Thru Seals G
in.
mm
0.750
19.0
1.250
31.7
in.
1.250
mm
31.7
2.390
See FA-1 Specification Guide
40FA/SA36
92.0
or
3.000
60DA36
Seal Bore
60.7
2.390
60.7
76.2
3.000
76.2
Accessory
Size ▼
See FA-1™ Specification Guide for sizes 5-in. (127.0 mm) 15–21 lb/ft and larger, ID casing.
FA-1™ and FAB-1™ Retainer Production Packer, Product Family Nos. H41307 and H41309
Packer n
Casing
Weight X
OD
in.
5
mm
127.0
5-1/2
139.7
6-5/8
7
Packer Sealing Bore
Size
Max OD
lb/ft
15–20.8
32.3–35.3
32FA30
32FA30
in.
3.968
3.968
mm
100.7
100.7
14–17
45FA36
4.562
115.8
Seal Bore
in.
3.000
3.000
3.625
13–14
47FA36
4.750
120.6
20–24
83FA47
5.687
144.4
168.2
177.8
17
85FA47
5.875
149.2
32–38
83FA47
5.687
144.4
26–32
85FA47
5.875
149.2
87FA47
89FA52
89FA52
91FA52
89FA52
194FA75
212FA75
6.000
6.250
6.250
6.500
6.250
8.438
9.000
152.4
158.7
158.7
165.1
158.7
214.3
228.6
240FA1025
11.975
301.6
7-5/8
193.6
7-3/4
9-5/8
10-3/4
196.9
244.4
273.0
20–23
17–20
33.7–42.8
24–33.7
45.1–48.6
36–47
60.7–79.2
13-3/8
339.7
68-85
Lower ⊕
Upper
mm
76.2
76.2
92.0
Seal
Assembly
Size ▼
20FA/SA30
20FA/SA30
40FA/SA36
or
60DA36
or
41FA/SA36
or
61DA36
Min Bore
Thru Seals G
in.
mm
2.390
60.7
2.390
60.7
3.000
Seal Bore ◆
73.0
Min Bore
Thru Seals G
in.
mm
1.865
47.3
1.865
47.3
in.
2.500
2.500
mm
63.5
63.5
3.000
76.2
42/62–30
or
40/60
2.375
or
1.970
60.3
or
50.0
76.2
2.875
Accessory
Size ▼
20–25
20–25
4.750
120.6
82FA47
or
81FA47
4.000
or
3.875
101.6
or
98.4
4.000
101.6
80–40
2.985
75.8
4.750
120.6
82FA47
or
81FA47
4.000
or
3.875
101.6
or
98.4
4.000
101.6
80–40
2.985
75.8
5.250
133.3
80FA/SA52
4.462
113.3
4.400
111.7
80–44
3.484
88.4
5.250
133.3
80FA/SA52
4.462
113.3
4.400
111.7
80–44
3.484
88.4
5.250
7.500
7.500
133.3
190.5
190.5
80FA/SA52
190FA75
190FA75
4.462
6.031
6.031
113.3
153.1
153.1
4.400
6.000
6.000
111.7
152.4
152.4
3.484
4.875
4.875
88.4
123.8
123.8
10.250
260.3
190FA1025
-
-
8.625
219.0
80–44
190–60
190–60
Seals Not
Available
-
-
See FA™ specification guide for sizes 4-1/2 in. (114.3 mm) and smaller.
X
l
n
‡
◆
▼
⊕
∆
G
Includes some drillpipe and line-pipe weights
When proposed for use in other than the casing-weight range shown contact your Baker Hughes representative
For information on packer or accessory sizes not found in this specification guide refer to Baker Hughes' packer systems technical manual or your
Baker Hughes representative
Does not contain a left-hand thread unless ordered.
The maximum OD (including tolerance) of any part run through a production packer should be at least 1/16-in. (1.59 mm) smaller than the minimum bore through the
packer body. This may occasionally require that the coupling ODs be turned down.
Tubing seal assemblies, tubing seal and spacer nipples
Lower bore can be used as a seal bore, HOWEVER, strict dimensional analysis for compatibility of packer bore/sealing accessory configuration is required to assure desire
performance. Compatibility is based on lower bore/seal nipple diametrical dimensions only. Final seating position of locating shoulder will very between packer sizes. Anchor
mechanisms are not recommended.
In 4-1/2 in. (114.3 mm) OD 11.6 lb and heavier casing the size 20 wireline pressure setting assembly is too large and the size 10 assembly must be used. In 4-1/2-in.
(114.3 mm) OD 9.5 and 10.5 lb casing, either the size 10 or 20 assembly may be used.
ID listed is for commonly used G-22™, E-22™ or K-22™ seal assemblies.
41
Permanent Packer Systems
FB-3 High-Pressure Retainer Production Packer
Product Family No. H41350
APPLICATION
The Baker Hughes FB-3™ high-pressure retainer production packer is designed for the extreme
hydrostatic- annulus pressures encountered during deep well tests. It’s most commonly used
in high-pressure DST completions, when the possible evacuation of tubing luids, during
perforating, could result in extreme loads on packers. The FB-3’s non-sealing bore differentiates
it from conventional FB-1™ packers. Seal-bore extensions attached below the packer will
function as the tubing-to-packer sealing device, while the packer effects a casing seal and
supports the induced loads.
Advantages
„„Packers
rated for differential pressures up to 15,000 psi dependent on size
possible opening through packer for high-pressure applications
„„Uniquely designed sealing element eliminates need for wire mesh in
extreme applications
„„One piece body with premium thread down for sealbore extension enhances reliability
„„Standard slips will grip V-150 casing
„„May be set with standard wireline or drillpipe setting tools
„„Largest
Additional Information
In cases of extreme annulus pressure from above, the seal assembly may be spaced out to prevent
contact with the locating shoulder to limit the transmission of compression into the packer.
The seal-bore sizes have been optimized, so large-diameter tubing-conveyed perforating guns can
be removed after iring.
SPECIFICATION GUIDE
OD
in.
mm
5
127.0
7
177.8
Casing
Weight
lb/ft
26.7
20.8
42.7
41 l
38–41 l
38
Model
Size
FB–3
HE Sp
22–23
396–26
82–38
83–36
83–40 Sp
83–36
83–40
83–40 Sp
83–40 Sp
83–40
87–40
FB–3
35
32
26
51.2
(50.91 Plain End)
7-5/8
l
193.6
55.3
47.1
45.3
42.8
39
FB–3
Packer Element
Packer
Type
OD
3.594
3.968
5.500
5.672
5.691
5.687
5.691
5.770
Nitrile
Nitrile
Aflas
Nitrile
Aflas
85–40 Sp
Nitrile
85–40
87–40
Aflas
5.800
6.000
5.875
6.000
Nitrile
89–40
Aflas
6.250
6.375
When proposed for use in other than the casing weight range shown contact your Baker Hughes representative.
NOTE: Contact your local Baker Hughes representative for information regarding pressure and temperature
ratings and elastomer availability.
42
FB-3 High-Pressure
Retainer Production Packer
Product Family No. H41350
Permanent Packer Systems
Granite™ No Downstroke, Hydraulic-Set
Retainer Production Packer
Product Family No. H40934
APPLICATION
The Granite packer is ideal for liner top and tandem completions since no downward mandrel
movement is required to set.
Advantages
„„High
performance–tested to ISO 14310–tested in gas with zero bubble leakage
body movement during setting–ideal for single- or multiple-packer completions
„„Solid, slim-lined construction–shares the same solid, slim-lined construction and
swab-resistant packing element as the SB™ packer
„„One-trip completion setting requires no rotation or reciprocation, eliminates spaceout and
landing problems
„„Seal integrity can be tested; unique design allows testing of all internal seals
before running
„„Modular-design packer configurable for threaded connections or with alternative
upper sealbore
„„Optional feed-through capability for use in downhole monitoring or
intelligent completions
„„No
SPECIFICATION GUIDE
Casing
OD
Packer
ID Range In Which
Packer May Be Run
Weight
Min
in.
7
mm
177.8
OD
Size
Max
ID
lb/ft
in.
mm
in.
mm
29–32
5.990
152.1
6.293
159.8
591–388
35
5.892
149.7
6.123
155.5
560–326
5.600
142.2
3.260
82.8
831–600
8.305
211.0
6.000
152.4
812–475
8.125
206.4
4.750
120.6
934–600
9.340
237.3
6.000
152.40
9-5/8
244.5
47–53.5
8.405
213.5
8.822
224.1
10-3/4
273.05
60.7–65.7
9.470
240.54
9.819
249.40
in.
mm
in.
mm
5.905
150.0
3.880
98.6
Granite No Downstroke,
Hydraulic Set Retainer Production Packer
Product Family No. H40934
43
Permanent Packer Systems
SB-3 Hydraulic-Set Retainer Production Packer
Product Family No. H40906
APPLICATION
Baker Hughes SB-3™ hydraulic-set retainer production packer is a one-trip, completion packer,
that is a hydraulically set version of the DB™ packer.
Advantages
„„Slim-line
design
construction enables faster run-in without fear of impact damage or premature
setting, making significant rig-time savings possible
„„Two opposed sets of full-circle, full-strength slips ensure packer will remain
properly set
„„Packing element resists swab-off and packs off securely when packer is set
„„Unique interlocking, expandable, metal backup rings contact casing, creating a
positive barrier to packing element extrusion
„„Flanged-up completions for safety
„„Setting requires no rotation or reciprocation, eliminating spacing out or
landing problems
„„All O-rings supported by backup rings to improve long-term seal integrity
„„SB-3 Packers designed for pressure differential up to 10,000 psi
„„All alloy materials within packer are suitable for H S service
2
„„Seal assembly, on which packer is run, serves as a seal nipple after packer is set,
providing single-run completion
„„B Guide, furnished as standard equipment, enables mill-out extension or other
component to be attached below the packer
„„Test fixtures permit high-pressure surface testing of O-ring seals and
tailpipe connections
„„Solid
Additional Information
A guide for seal-bore extension can be furnished if required. The packer is also available in S-3™
(box x pin) coniguration by special order
Packer Accessories
Sealing systems; expansion joints; plugging devices; packer bore receptacles; SB-3 retainer
production packer with B™ guide for mill-out extension, Product Family No. H40906 (Nitrile) and
Product Family No. H40924 (Alas)
SB-3 Hydraulic-Set Retainer
Production Packer
Product Family No. H40906
44
Permanent Packer Systems
SPECIFICATION GUIDE
SB-3™ Hydraulic-Set Retainer Production Packer, Product Family No. H40906
Packer n
Casing
Weight X
OD
in.
mm
in.
mm
21–19
in.
mm
1.312
33.3
32–19
3.968
100.7
1.968
49.9
20–19
0.984
24.9
5-1/2
139.7
13–17
44–25
4.500
114.3
2.500
63.5
20–25
1.865
47.3
17–32
82–32
5.468
138.8
6-5/8
168.2
3.250
82.5
80–32
or
81–32
2.406
or
1.990
61.1
or
50.5
3.250
82.5
80–32
or
81–32
2.406
or
1.990
61.1
or
50.5
3.250
82.5
80–32
or
81–32
2.406
or
1.990
61.1
or
50.5
2.406
or
1.990
61.1
or
50.5
177.8
84–32
5.687
144.4
32–38
82–32
5.468
138.8
20–32
84–32
5.687
144.4
17–20
88–32
6.187
157.1
33.7–39
88–32
6.187
157.1
193.6
24–33.7
92–32
6.375
161.9
7-3/4
196.9
46.1–48.6
88–32
6.187
157.1
3.250
82.5
80–32
or
81–32
8-5/8
219.0
24–36
128–40
7.500
190.5
4.000
101.6
80/120–40
3.000
76.2
190–47
3.000
76.2
191–47
2.500
63.5
9-5/8
9-7/8
‡
mm
15–21
7-5/8
n
Min Bore Thru Seals ‡
Size
in.
127.0
7
l
Seal Bore
5
17–20
X
Size l
lb/ft
Standard Seal Assembly
OD
244.4
250.1
194–47
8.125
206.3
4.750
120.6
192–47
3.875
98.4
194–60 X
8.250
209.5
6.150
156.2
190–60
4.875
123.8
190–47
3.000
76.2
194–47
8.125
206.3
4.750
120.6
191–47
2.500
63.5
192–47
3.875
98.4
194–60 X
8.250
209.5
6.150
156.2
190–60
4.875
123.8
32.3–53.5
62.8
Includes some drillpipe and line-pipe weights.
When proposed for use in other than the casing-weight range shown contact your Baker Hughes representative.
For information on packer or accessory sizes not found in this specification guide refer to Baker Hughes' packer systems technical manual or your
Baker Hughes representative.
ID listed is for commonly used G-22™ and E-22™ seal assemblies.
45
Permanent Packer Systems
SAB-3 and SABL-3 Hydraulic-Set
Retainer Production Packers
Product Family Nos. H40907 and H40908
APPLICATION
Baker Hughes SAB-3™ and SABL-3™ hydraulic-set retainer production packers are the
hydraulically set versions of the DAB™ and FAB™ packers, respectively. These packers
feature the largest possible bore through combined packer and seal accessory. The
packer is run to depth, connected to the tubing with a K™ or KC™ anchor tubing seal
nipple and is set by applied tubing pressure. This makes the packer ideal for highangle deviated wells, common in offshore operations.
Advantages
„„Slim-line
design
construction enables 50% faster run-in without fear of impact
damage or premature setting, making significant rig-time savings possible
„„Two opposed sets of full-circle, full-strength slips ensure packer will
remain properly set
„„Packing element resists swab-off and packs off securely when packer is set
„„Unique interlocking, expandable, metal backup rings contact casing,
creating a positive barrier to packing element extrusion
„„Aflas™ packing element is available in select casing-weight ranges
„„Solid
Additional Information
The SAB-3 and SABL-3 packers have been designed to give maximum strength,
uniformity of setting pressure and standardization of all alloy materials for
H2S service.
The SAB-3 packers offer bores comparable to the DA™ packers in their
corresponding sizes.
The SABL-3 (large-bore) packers offer larger bores more comparable to the FA™
packers and as a result carry a lower-pressure rating than the SAB-3 packer.
The SABL-3 packers are only available in standard sizes.
Packer Accessories
Sealing systems; expansion joints; parallel low systems; plugging devices; packerbore receptacles
SAB-3 Hydraulic-Set Retainer
Production Packer with B Guide
Product Family No. H40907
46
Permanent Packer Systems
SPECIFICATION GUIDES
SAB-3™ Hydraulic-Set Retainer Production Packer, Product Family No. H40907
Packer X
Casing
Weight l
OD
in.
mm
Packer Sealing Bore
Max
OD
Size ▲
lb/ft
in.
Lower n
Upper
Seal Bore
mm
in.
mm
Seal
Assembly
Size
Min Bore
Thru Seals
in.
Seal Bore
mm
in.
mm
Min Bore
Thru Seals
Seal
Assembly
Size
in.
mm
20–19
.984
24.9
5
127.0
15–21
32SAB30 x 19
3.968
100.7
3.000
76.2
20FA30
2.390
60.7
1.968
49.9
21–19
1.312
33.3
5-1/2
139.7
13–17
44SAB32 x 25
4.500
114.3
3.250
82.5
40DA32
2.500
63.5
2.500
63.5
20–25
1.865
47.3
17–32
82SAB40 x 32
5.468
138.8
17–20
84SAB40 x 32
5.687
144.4
4.000
101.3
80DA40
3.250
82.5
3.250
82.5
80–32
2.406
61.1
32–44
82SAB40 x 32
5.468
138.8
20–32
84SAB40 x 32
5.687
144.4
4.000
101.3
80DA40
3.250
82.5
3.250
82.5
80–32
2.406
61.1
17–20
88SAB40 x 32
6.187
157.1
33.7–39
88SAB40 x 32
6.187
157.1
24–39
92SAB40 x 32
6.375
161.9
4.000
101.3
80DA40
3.250
82.5
3.250
82.5
80–32
2.406
61.1
6-5/8
168.2
7
177.8
193.6
7-5/8
7-3/4
196.9
46.1–48.6
88SAB40
6.187
157.1
4.000
101.3
80DA40
3.250
82.5
3.250
82.5
80–32
2.406
61.1
8-5/8
219.0
24–36
128SAB47 x 40
7.500
190.5
4.750
120.6
81FA47
3.875
98.4
4.000
101.6
80/120–40
3.000
76.2
191–47
2.500
63.5
190–47
3.000
76.2
192–47
3.875
98.4
-
-
-
191–47
2.500
63.5
190–47
3.000
76.2
192–47
3.875
98.4
-
-
-
244.4
9-5/8
32.3–58.4
194SAB60 x 47
206.3
8.125
152.4
6.000
190DA60
4.875
123.8
194SAB60 x 48
250.1
9-7/8
62.8
194SAB60 x 47
4.750
4.895 ‡
206.3
8.125
152.4
6.000
190DA60
4.875
123.8
194SAB60 x 48
4.750
4.895 ‡
120.6
124.3
120.6
124.3
SABL-3 Hydraulic-Set Retainer Production Packer, Product Family No. H40908
Packer X
Casing
Packer Sealing Bore
Lower n
Upper
Weight l
OD
in.
mm
lb/ft
in.
mm
in.
mm
in.
mm
in.
mm
5-1/2
139.7
20–23
43SABL36 x 27
4.450
113.0
3.625
92.0
43SA36
2.780
70.6
2.780 ‡
70.6
-
-
-
6-5/8
168.2
17
85SABL47 x 38
5.875
149.2
4.750
120.6
81FA47
3.875
98.4
3.875
98.4
120–38
2.500
63.5
in.
mm
177.8
26–29
85SABL48 x 4.145
5.875
149.2
4.875
123.8
80DA48
4.125
104.7
4.125 ‡
104.7
-
-
-
193.6
24–33.7
91SABL47 x 38
6.500
165.1
4.750
120.6
81FA47
3.875
98.4
3.885
98.6
120–38
2.500
63.5
8-5/8
219.0
24–36
128SABL60 x 47
7.500
190.5
6.000
152.4
190DA60
4.875
123.8
4.750
120.6
190–47
3.000
76.2
190SA73
6.000
152.4
6.000
152.4
190–60
4.875
123.8
190–73
6.059
153.8
6.059 ‡
153.8
-
-
-
80DA40
3.250
82.5
3.250
82.5
80–32
2.406
61.1
9-7/8
244.4
47–58.4
194SABL73 x 6.059
194SABL40 x 32
250.1
62.8
194SABL73 x 6.059
194SABL40 x 32
194SABL47 x 44
10-3/4
‡
Seal Bore
7
194SABL73 x 60
▲
Seal Bore
7-5/8
194SABL47 x 44
n
Min Bore
Thru Seals
Seal
Assembly
Size
9-5/8
l
Min Bore
Thru Seals
Seal
Assembly
Size
Size ▲
194SABL73 x 60
X
Max OD
273.0
32.75–60.7
214SABL73 x 60
8.250
8.125
8.250
209.5
206.3
209.5
8.125
206.3
9.437
239.7
7.375
187.3
4.000
101.6
4.750
120.6
7.375
187.3
4.000
101.6
81FA47
3.875
98.4
4.400
111.7
80–44
3.500
88.9
190SA73
6.000
152.4
6.000
152.4
190–60
4.875
123.8
190–73
6.059
153.8
6.059 ‡
153.8
-
-
-
80DA40
3.250
82.5
3.250
82.5
80–32
2.406
61.1
4.750
120.6
81FA47
3.875
98.4
4.400
111.7
80–44
3.500
88.9
7.375
187.3
190SA73
6.000
152.4
6.000
152.4
190–60
4.875
123.8
For information on packer or accessory sizes not found in this specification guide refer to Baker Hughes' packer systems technical manual or your
Baker Hughes representative.
Includes some drillpipe and line pipe weights.
Lower bore can be used as a seal bore, HOWEVER, strict dimensional analysis for compatibility of packer bore/sealing accessory configuration is required to assure desire
performance. Compatibility is based on lower bore/seal nipple diametrical dimensions only. Final seating position of locating shoulder will very between packer sizes. Anchor
mechanisms are not recommended.
When proposed for use in other than the casing-weight range shown, contact your Baker Hughes representative.
This is not a honed seal bore.
47
Permanent Packer Systems
Baker Retainer Production Packer
with Aflas Element System
Product Family Nos. H42425, H42426, H42432, H42525, H42526, H42532, H42625, H42626,
H42632, H42725, H42726, H42732, H41525, H41526, H41340, H41341, H40924, H40925,
H40926, H41598 and H41599
D™, DB™, DA™, DAB™, F-1™, FB-1™, FA-1™, FAB-1™, SB-3™, SAB-3™ and SABL-3™ with high-performance
Alas* element systems have been developed for aggressive well environments. Packers with Alas element
systems are service rated from 110°F to 450°F (43°C to 232°C).
Advantages
„„Provides
a reliable long-term seal
its mechanical and chemical properties better than nitrile in aggressive environments
„„Dependable at temperatures above 300°F (149°C)
„„Retains
Can be used:
H2S is present above 175°F (79°C) and at greater than 100 ppm below 175°F (79°C)
„„In bromide completions
„„In amine inhibitors above 175°F (79°C)
„„In high-pH completion fluids
„„When
Additional Information
Restricted casing ranges:
Please carefully review the casing ranges shown in the speciication guide; ranges are more restrictive than
packers with nitrile elements.
Baker Retainer Production Packer
with Aflas Element System
Product Family No. H41340
Please note: permanent packers with Alas element systems cannot be turned down and run in heavierweight casing than speciied in the speciication guide.
SPECIFICATION GUIDE
D and DA Retainer Production Packers With Aflas
Casing
OD
in.
4-1/2
4-1/2
5
n
X
Weight
mm
114.3
114.3
127
5
127
5-1/2
139.7
6-5/8
7
168.3
177.8
(lb/ft)
16.9–18.8
9.5–12.6
23.2–24.1
Packer
ID Range In Which
Packer May Be Run
Min
Max
in.
mm
in.
mm
3.549
50.1
3.823
97.1
3.920
99.6
4.090
103.9
19–19
in
3.460
mm
47.9
lb
33,000
kg
14 968
Max Acceptable
Cool Down From
Setting Temp
°F
°C
200
93
23–26
3.750
95.3
33,000
14 968
340
171
3.968
100.8
55,000
24 947
340
171
4.328
4.500
109.9
114.3
55,000
24 947
340
330
171
165
5.468
138.9
55,000
24 947
225
107
55,000
24 947
165
73
Size
15–18
4.125
104.8
4.436
112.7
20–23
13–17
17–28
32–41
4.578
4.812
116.3
122.2
4.818
5.044
122.4
128.1
32–25
32–26
42–26
44–26
5.675
144.1
6.161
156.5
82–32
6-5/8
7
168.3
177.8
17–20
23–32
6.049
7
7-5/8
177.8
193.7
17–23
33.7–45.3
6.284
159.6
6.765
171.8
9-5/8
244.5
36–53.5
8.405
213.5
9.001
228.6
153.6
6.466
164.2
84–32
84–26
84DA40x32
88–32 n
88–30 n
88–26 n
88DA40x32
194–47
194–40
194–32
194–30
194DA60x47
Required
Setting Force
Max OD
5.687
144.4
6.187
157.1
6.187
157.1
55,000
24 947
250
121
8.125
206.4
55,000
24 947
250
121
88-32, 88-30, 88-26 sizes can be run in 7-5/8-in. (193.7 mm) 29.7 lb/ft casing rated to 8,000 psi above or below combined with 50,000 lb tension to 330˚F (165˚C).
19-19 tested to 400˚F (204˚C) maximum temperature.
*Aflas is a registered trademark of Asahi Glass of Japan.
48
Permanent Packer Systems
SPECIFICATION GUIDES
F-1™ and FA-1™ Retainer Production Packers With Aflas™
Casing
OD
Packer
ID Range In Which
Packer May Be Run
Weight
Min
X
in.
5
mm
127
5-1/2
139.7
Size
Max
5-1/2
139.7
lb/ft
15–18
20
23
14–17
29.7
in.
4.125
4.625
4.578
4.812
4.257
mm
104.8
117.5
116.3
122.2
108.1
in.
4.436
4.868
4.766
5.012
4.488
mm
112.7
123.6
121.1
127.3
114.0
6-5/8
7
168.3
177.8
20
35
5.875
149.2
6.094
154.8
7
177.8
26–29
6.088
154.6
6.381
162.1
9-5/8
244.5
43.5–53.5
8.405
213.5
8.822
224.1
32FA30x25
43–30
41–30
45–30
33FA30 
83–40
83FA47x40
85–40
85FA47x40
192–60
192FA73x60
Max
OD
3.968
Required
Setting Force
lb
55,000
kg
24 947
55,000
24 947
Max Acceptable
Cool Down From
Setting Temp
°F
340
°C
171.1
250
121.1
24 947
340
250
171.1
121.1
55,000
24 947
175
79.4
5.875
55,000
24 947
340
171.1
8.218
8.203
55,000
24 947
200
93.3
4.437
4.562
4.100
55,000
5.687
33FA30 was tested to 425˚F (218˚C) maximum temperatures. It can be run in 5-1/2-in. (139.7 mm) 29.7 lb/ft casing rated to 15,000 psi above or
below combined with 140,000 lb tension/compression (H427-26-3203).
SAB-3™ AND SB-3™ Hydraulic-Set Retainer Production Packers With Aflas
Casing
OD
Weight
ID Range In Which
Packer May Be Run
Min
Max
in.
mm
in.
mm
in.
mm
lb/ft
6-5/8
7
168.3
177.8
17–28
32–41
5.675
144.1
6.135
155.8
6-5/8
7
168.3
177.8
17
23–32
6.049
153.6
6.366
161.7
9-5/8
244.5
36–53.5
8.405
213.5
9.001
228.6
Size
82SAB40x32
82SAB32x25
82-32 SB-3
84SAB40x32
84SAB40x29
84SAB40x27
84-32 SB-3
194SAB60x48
194SAB60x47
194SAB60x40
194SAB47x44
194SAB47x40
194SAB47x38
194SAB47x30
194-47 SB-3
194-40 SB-3
194-32 SB-3
Max
OD
Packer
Required
Setting
Pressure
psi
bar
Max Acceptable
Cool Down From
Setting Temp
°F
°C
5.468
4,000
276
340
171.1
5.687
4,000
276
290
143.3
8.125
4,000
276
250
121.1
SABL-3™ and SB-3 Hydraulic-Set Retainer Production Packers With Aflas
Casing
OD
in.
Weight
mm
lb/ft
Packer
ID Range In Which
Packer May Be Run
Min
Max
in.
mm
in.
mm
7
177.8
26–29
6.088
154.6
6.276
159.4
9-5/8
244.5
47–53.5
8.405
213.5
8.822
224.1
Size
85SABL47x39
85SABL47x38
85SABL47x36
194SABL75x60
194SABL73x60
194-60 SB-3
psi
bar
Max Acceptable
Cool Down From
Setting Temp
°F
°C
5.875
5,000
345
175
79.4
8.250
4,000
276
250
121.1
Max
OD
Required
Setting Pressure
S-3™ Hydraulic-Set Retainer Production Packers With Aflas
Casing
OD
Weight
Packer
ID Range In Which
Packer May Be Run
Min
Max
in.
mm
in.
mm
in.
mm
lb/ft
7-5/8
193.7
39
6.510
165.1
6.750
171.5
7-3/4
196.8
46.1
6.500
165.4
6.696
170.1
Size
89–38
S–3
89–38
S–3
psi
bar
Max Acceptable
Cool Down From
Setting Temp
°F
°C
6.380
4,000
276
200
93.3
6.380
4,000
276
200
93.3
Max
OD
Required
Setting Pressure
49
Retrievable Packer Systems
RETRIEVABLE PACKER SELECTION CHART
Holds
Pressure From
3
8
X
X
ADL-1 Large Bore Tension Packer
H73912
X
X
3
8
X
X
AL-2 Large Bore LOK-SET
Retainer Casing Packer
H64628
X
C-1 Invertible Packer
H73930
X
X
C-1 Tandem Tension Packer
H60226
X
X
G Compression Packer
H42003
X
Hornet
H64682
X
MJS Thermal Packer
H41754
X
R-3 Double Grip Packer
H64201
X
R-3 Single Grip Packer
H64101
X
Sabre
H64668
X
X
5
X
X
5
X
4
9
9
4
8
X
X
4
X
8
X
X
5
X
1
1
6
X
X
4
X
X
4
X
5
X
X
X
X
X
X
X
X
X
X
X
X
X
X
8
X
X
X
X
X
X
X
X
X
X
Single String, Hydraulic/Hydrostatic Set Packers
FH Hydrostatic Packer
H78108
X
X
6
X
FHL Large Bore Hydrostatic Packer
H78120
X
X
6
X
X
HS Hydraulic Set Packer
H78460
X
X
6
X
X
Premier Packer
H78463
X
X
10
X
X
Single String, Setting Tool Set, Sealbore Packers
SC-2 Retrievable Sealbore Bore Packer
H48807
X
2
7
X
X
H64683
X
X
5
X
X
H64710/11
X
X
5
X
X
6
X
X
X
Single String, Wireline Set Packers
Hornet EL
WL, Reliant Series
Dual String, Hydraulic/Hydrostatic Set Packers
A-5 Hydrostatic Dual Packer
H78316
AL-5 Hydrostatic Dual Packer
H78330
ElecPak
H78570
GT DSR Dual Packer
Twin Seal Submersible Pump Packer
X
X
X
H78509/10
H78540
X
X
X
X
6
X
X
6
X
X
6
X
X
6
X
X
X
X
X
Tubing Hangers
Mudline Tubing Hanger
H79101
X
X
6
FLX Pack-Off Tubing Hanger
H79085
X
X
6
NOTES:
(1) Set mechanically by torquing tubing string to right
(2) Can also be set using by hydraulic setting tools run on a workstring
(3) Released by relieving applied tension required to rupture shear ring
(4) Released by relieving applied setting force
(5) Released with right-hand rotation
(6) Released with applied tension required to rupture shear ring
(7) Released and removed from well with releasing tool run on tubing or workstring
(8) Holds limited differential pressure from this direction
(9) Ability to hold differential pressure is governed by packer's orientation
(10) Released by severing mandrel
50
X
X
X
Multilateral
X
Single String, Mechanical Set Packers
Thermal
X
Deepwater
X
H73908
Elec Pump
H64630
AD-1 Tension Packer
Isolation
Production/
Stimulation
Waterflood/
Injection
A-3 LOK-SET Retainer Casing Packer
Both
Below
Releasing
Method
Primary Applications
Above
Compression
Tension
Product Single Multiple
Family No. String String
Hydraulic
Product Application
Wireline
Setting Method Used
Retrievable Packer Systems
AD-1 and ADL-1 Tension Packers
Product Family Nos. H73908 and H73912
APPLICATION
The AD-1™ tension packer is a compact, economical, retrievable packer.
Primarily used in waterlood applications, it can also be used for production,
treating operations, and when a set-down packer is impractical. And because
the AD-1 is tension-set, it is ideally suited for shallow wells where set-down
weight is not available.
Advantages
„„Uses
Baker Hughes rugged rocker-type slips
mandrel is larger than drift
„„Simple, low-cost packer for fluid injection
„„Three release methods ensure retrievability
„„Uses proven one-piece packing element
„„Bore-through-the-packer
Additional Information
The ADL-1™ tension packer is a large-bore version of the AD-1 and offers the
same features and beneits; running and retrieving operations are also the same.
AD-1 Tension Packer
Product Family No. H73908
51
Retrievable Packer Systems
SPECIFICATION GUIDES
AD–1™ Tension Packer, Product Family No. H73908
Casing
Packer
Weight X
OD
Size
in.
mm
lb/ft
4
101.6
9.5–11.6
41A
4-1/2
114.3
12.6–15.1
41B
9.5–13.5
43A
5
127.0
139.7
5-1/2
146.1
5-3/4
152.4
6
168.3
6-5/8
177.8
7
193.7
7-5/8
219.1
8-5/8
244.5
9-5/8
15–18
43B
11.5–15
43C
26
43C
20–23
45A2
15.5–20
45A4
13–15.5
45B
22.5
45B
26
45B
Nom ID
Max Gage Ring OD
in.
mm
in.
mm
1.890
48.1
3.281
83.3
1.890
48.1
1.890
48.1
1.890
48.1
49.6
1.953
49.6
1.953
91.7
3.786
96.2
4.140
105.2
4.265
108.3
4.265
108.3
4.515
114.7
4.656
118.3
4.796
121.8
4.796
121.8
4.796
121.8
20–23
45C
5.077
129.0
15–18
45D
5.171
131.3
34
45E2
5.421
137.7
28–32
45E4
24
47A2
17–20
47A4
38
47A2
32–35
47A4
26–29
47B2
49.6
3.609
1.953
49.6
1.953
61.2
2.409
61.2
2.409
5.499
139.7
5.671
144.0
5.827
148.0
5.671
144.0
5.827
148.0
5.983
152.0
20–26
47B4
6.093
154.8
17–20
47C2
6.281
159.5
33.7–39
47C4
6.468
164.3
24–29.7
47D2
6.687
169.9
20–24
47D4
6.827
173.4
40–49
49A2
7.327
186.1
32–40
49A4
7.546
191.7
20–28
49B
7.796
198.0
47–53.5
51A2
8.218
208.7
8.437
214.3
8.593
218.3
40–47
51A4
29.3–36
51B
61.2
2.409
76.2
3.000
101.6
4.000
10-3/4
273.1
32.7–55.5
53A
4.000
101.6
9.515
241.7
11-3/4
298.5
38–60
53B
4.000
101.6
10.515
261.1
12-3/4
323.9
48–53
55A
4.000
101.6
11.625
295.3
13-3/8
339.7
48–72
55B
4.000
101.6
12.000
304.8
ADL–1™ Tension Packer, Product Family No. H73912
Casing
OD
Packer
Weight
X
Nom ID
Gage Ring OD
Size
in.
mm
lb/ft
5-1/2
139.7
13–17
45B x 2.90
152.4
23–26
45C x 2.90
6
7
8-5/8

177.8
219.1
in.
mm
in.
mm
2.903
73.7
4.750
120.7
73.7
5.000
127.0
2.903
18–20
45D x 2.90
5.218
132.5
23–29
47B x 4.12
5.983
152.0
17–20
47C2 x 4.12
24–32
49A4 x 4.00
4.125
104.8
4.000
101.6
6.281
159.5
7.615
193.4
When selecting a packer for a casing weight common to two weight ranges (same OD), choose the packer size shown for the lighter of the two weight ranges.
Example: for 7-in. (177.8 mm) 20 lb/ft casing use packer size 47C2. Under certain circumstances the other packer size may be run, such as when running in mixed
casing strings. Repair kits, including items as packing elements, seal strings, etc., are available for redressing retrievable packers. Contact your Baker Hughes
representative. Use only on Baker Hughes repair parts.
52
Retrievable Packer Systems
G Retrievable Casing Packer
Product Family No. H42003
APPLICATION
The G™ packer is an economical, compression-set packer, intended for lowerpressure production applications.
Advantages
„„Rugged
rocker-type slips system
length
„„Full-opening bore through packer
„„Low cost
„„Safety joint for emergency disconnect
„„Compact
Additional Information
It is set by one-quarter-turn right-hand rotation. Release is accomplished by
straight pickup of the tubing. If it is necessary to move the packer further
downhole after release, one-fourth-turn left-hand rotation will put the tool back
into the running position.
C-1 Single Grip Invertible Packer
Product Family No. H73930
APPLICATION
The C-1™ packer can be run as a conventionally set packer or, when run upside
down, it can be set in compression. Emergency releases are provided for tension
and compression operations.
G Retrievable Casing Packer
Product Family No. H42003
53
Retrievable Packer Systems
SPECIFICATION GUIDES
G™ Retrievable Casing Packer, Product Family No. H42003
Casing
Packer
Weight X
OD
in.
4-1/2
mm
114.3
5
127.0
5-1/2
139.7
5-3/4
146.1
6
152.4
6-5/8
168.3
lb/ft
9.5–13.5
15–18
11.5–15
26
20–23
15.5–20
13–15.5
22.5
26
20–23
15–18
34
28–32
24–28
24
17–20
38
32–35
7
177.8
26–29
20–26

7-5/8
193.7
8-5/8
219.1
9-5/8
244.5
10-3/4
11-3/4
12-3/4
13-3/8
273.1
298.5
323.9
339.7
17–20
33.7–39
24–29.7
20–24
40–49
32–40
20–28
47–53.5
40–47
29.3–36
32.75–55.5
38–60
43–53
48–72
Size
43A
43B
43C
43C
45A2
45A4
45B
45B
45B
45C
45D
45E2
45E4
46A4
47A2
47A4
46A4
47A2
47A4
47B2
47B2 x 3.00
47B4
47BA x 3.00
47C2
47C4
47D2
47D4
49A2
49A4
49B
51A2
51A4
51B
53A
53B
55A
55B
Max Cone and
Guide Ring OD
Nom ID
in.
1.895
mm
48.1
1.895
48.1
1.895
48.1
1.973
50.1
1.973
50.1
1.973
50.1
1.973
50.1
2.416
61.4
2.416
61.4
3.000
2.416
3.000
2.416
76.2
61.4
76.2
61.4
2.416
61.4
3.000
76.2
4.000
101.6
4.000
4.000
4.000
4.000
101.6
101.6
101.6
101.6
in.
3.786
4.140
4.265
4.265
4.515
4.656
4.796
4.796
4.796
5.077
5.171
5.421
5.499
5.603
5.671
5.827
5.603
5.671
5.827
mm
96.2
105.2
108.3
108.3
114.7
118.3
121.8
121.8
121.8
129.0
131.3
137.7
139.7
142.3
144.0
148.0
142.3
144.0
148.0
5.983
152.0
6.093
154.8
6.281
6.468
6.687
6.827
7.327
7.546
7.796
8.233
8.452
8.608
9.515
10.515
11.640
12.015
159.5
164.3
169.9
173.4
186.1
191.7
198.0
209.1
214.7
218.6
241.7
267.7
295.7
305.2
When selecting a packer for a casing weight common to two weight ranges (same OD), choose the packer size shown for the lighter of the two weight ranges.
Example: For 5-1/2-in. (139.7-mm)-OD 20-lb/ft casing, use packer size 45A4.
Under certain circumstances the other packer size may be run, such as when running in mixed casing strings.
C-1™ Single-Grip Invertible Packer, Product Family No. H73930
Casing
OD

l
Packer
Weight
in.
2-3/8
mm
60.3
2-7/8
73.0
3-1/2
88.9
4
101.6
4-1/2
114.3
lb/ft
4.6–5.3
6.4–6.5
4.7–5.6
10.2
7.7–9.3
5.75
15.70 X
9.5–11.6
12.6–15.1 l
Nom ID
Size
23
28A
28B
35A
35B
35C
35D
41A
41B
in.
.625
mm
15.9
1.000
25.4
1.531
38.9
1.531
1.978
1.978
38.9
50.2
50.2
Max Cone, Guide or
Bottom Sub OD
in.
mm
1.813
46.1
2.219
56.4
2.357
59.9
2.764
70.2
2.812
71.4
3.029
76.9
3.029
76.9
3.281
83.3
3.609
91.7
Plain End: 14.69 lb
Plain End: 12.24–14.98 lb
NOTE: Repair kits, including such items as packing elements, seal rings, etc., are available for redressing retrievable packers. Contact your Baker Hughes representative. Use
only genuine Baker Hughes repair parts.
54
Retrievable Packer Systems
R-3 Double Grip Retrievable Casing Packer
Product Family No. H64201
R-3 Single Grip Retrievable Casing Packer
Product Family No. H64101
APPLICATION
The R-3™ packer is a versatile production packer intended for a broad
range of production applications. It is a compression-set packer, suitable
for stimulation and treating applications in a double-grip coniguration.
Applications in which excessive bottomhole pressures have been depleted,
a single-grip version can be used as an economical production packer.
Advantages
„„Rugged
rocker-type slips system
button-type hold-down located below bypass valve
„„Unique, built-in differential lock helps keep bypass closed
„„Effective bypass design allows rapid pressure equalization and
resists swab off
„„Field-proven, three-piece packing element system
„„Hydraulic
Additional Information
The R-3 single-grip retrievable-casing packer is set with one-fourth-turn
right-hand rotation and can be released with straight pickup.
R-3 Retrievable Casing
Packer Double Grip
Product Family No. H64201
55
Retrievable Packer Systems
SPECIFICATION GUIDES
R-3™ Double-Grip and Single-Grip Retrievable Casing Packers, Product Family Nos. H64201 and H64101
Casing
OD
in.
mm
2-7/8
73.0
3-1/2
88.9
4
101.6
4-1/2
114.3
5
127.0
5-1/2
139.7
Weight X
lb/ft
6.4–6.5
4.7–5.6
10.2
7.7–9.2
5.75
9.5–11.6
15.1
9.5–13.5
15–18
11.5–15
26
20–23
15.5–20
17–20
13–15.5
5-3/4
146.1
6
152.4
22.5
26
20–23
15–18
34
28–32
6-5/8
168.3
24–28
24
17–20
20
17
38
32–35
7
177.8
26–29
20–26
17–20
33.7–39
7-5/8
193.7
24–29.7
20–24
X
l
n
▲
8-5/8
219.1
9-5/8
244.5
44–49
32–40
20–28
47–53.5
40–47
29.3–36
Packer
Size l
28A
28A Hi-Temp n
28B
35A
35B
35C
41A
41B
43A
43B
43C
43C
45A2
45A2 x 2-3/8
45A4
45A4 x 2-3/8
45B
45B x 2-3/8
45B
45B x 2-3/8
45B
45B x 2-3/8
45C
45D
45E2
45E4
46A2
45EF
46A4
47A2
47A4
47A4 x 3.00
47B2 x 3.00
46A4
47A2
46B
47A4
47A4 x 3.00
47B2
47B2 x 3.00
47B4
47B4 x 3.00
47C2
47C2 x 3.00
47C4
47C4 x 3.00
47D2
47D4
47D4 x 3.00
49A2
49A4
49B2
51A2
51A4
51B2
Nom ID
in.
mm
.750
19.1
1.375
34.9
1.500
1.500
1.850
1.850
1.850
1.850
1.930
2.365
1.930
2.365
1.930
2.365
1.930
2.365
1.930
2.365
38.1
38.1
48.0
48.0
48.0
48.0
49.9
60.3
49.9
60.3
49.9
60.3
49.9
60.3
49.9
60.3
1.930
49.9
1.930
49.9
2.406 ▲
1.963
61.0
49.9
2.406 ▲
61.0
3.000
76.2
2.406
61.0
3.000
2.406 ▲
3.000
2.406 ▲
3.000
2.406 ▲
3.000
2.406 ▲
3.000
76.2
61.0
76.2
61.0
76.2
61.0
76.2
61.0
76.2
2.406 ▲
61.0
3.000
76.2
3.476
88.3
3.958
100.5
Max Gage & Guide Ring OD
in.
mm
2.234
56.7
2.330
51.2
2.357
59.9
2.782
70.7
2.844
72.2
3.038
77.2
3.303
83.9
3.620
92.0
3.786
96.2
4.140
105.2
4.265
108.3
4.265
108.3
4.515
114.7
4.656
118.3
4.796
121.8
4.796
121.8
4.796
121.8
5.078
5.171
5.421
5.499
5.490
5.499
5.603
5.671
129.0
131.3
137.7
139.7
139.5
139.7
142.3
144.0
5.827
148.0
5.983
5.603
5.671
5.796
152.0
142.3
144.0
147.2
5.827
148.0
5.939
150.9
6.093
154.8
6.281
159.5
6.468
164.3
6.687
169.9
6.827
173.4
7.327
7.546
7.796
8.233
8.453
8.608
186.1
191.7
198.0
209.1
209.1
218.6
When selecting a packer for a casing weight common to two weight ranges (same OD), choose the packer size shown for the lighter of the two weight ranges. Example: for
7-in. (177.8 mm) OD 20 lb/ft casing use packer size 47C2. Under certain circumstances the other packer size may be run, such as when running in mixed casing strings.
Sizes 28, 32, 41 are available in this model as single-grip packers, Product Family No. H64101. For double-grip version, contact your Baker Hughes representative about
the RC hydraulic-grip cementer, Product Family No. H40720.
For use when anticipated conditions exceed 200˚F (93.33˚C) or 3,800 psi (26.18 MPa) differential across tool.
2.347-in. (60.0 mm) x 42 in. (1.067 mm) drift bar
Repair kits, including such items as packing elements, seal rings, etc., are available for redressing retrievable packers. Contact your Baker Hughes representative.
Use only genuine Baker Hughes repair parts.
56
Retrievable Packer Systems
A-3 and AL-2 LOK-SET Retrievable
Casing Packers
Product Family No. H64630 and H64628
APPLICATION
The A-3™ LOK-SET™ packer combines advantages of a retrievable packer with
the features of a permanent packer. An ability to lock down tubing forces makes
the A-3 suitable for a broad range of applications, including production, injection,
zone isolation, and remedial operations. The AL-2™ LOK-SET packer is similar to
the A-3, and has a larger bore.
Advantages
„„Holds
pressure from above and below, without relying on set-down
weight, tubing tension, or hydraulic hold down
„„Provides tubing anchoring with tension applied, suitable for pumping
wells or injection, controlling tubing forces related to change
fluid temperatures
„„Opposed, non-transferring, dovetail slips prevent packer movement
associated with changing differential pressures, while allowing the
landing of the tubing in tension, neutral or compression
„„Right-hand tubing rotation controls setting and releasing
„„Packing element compression locks in by ratcheting action of lock
segments, which restricts rotation to one direction
Accessories
To provide a simple and reliable injection system for retrieving an injection string
without having to unseat the packer:
L-10 or L-316 on-off sealing connectors, Product Family Nos. H68420 and
H68422. Baker Hughes blanking plug can be used in the seating nipple proile of
the on-off sealing connector to provide a means of plugging the lower zone while
the tubing is being pulled.
A-3 LOK-SET
Retrievable Casing Packer
Product Family No. H64630
57
Retrievable Packer Systems
SPECIFICATION GUIDES
A-3™ LOK-SET Retrievable Casing Packer, Product Family No. H64630
Casing
Packer
Weight X
OD
in.
4
4-1/2
4
mm
101.6
144.3
101.6
4-1/2
114.3
5
127.0
5-1/2
139.7
6
152.4
6-5/8
168.3
7
177.8
7-5/8
193.7
8-5/8
219.1
9-5/8
244.5
lb/ft
9.5–12.9
21.6–23.6
9.5
18.8
13.5–17.7
11.6–13.5
9.5–10.5
15–18
11.5–15
26
20–23
15.5 –20
13–15.5
26
20–23
15–18
34
24–32
24
17–24
17–20
38
32–35
26–29
23–26
17–20
33.7–39
24–29.7
20–24
44–49
32–40
20–28
47–53.5
40–47
29.3–36
Max Gage
Ring OD
Nom ID
Size
41A2
41A2
41A4
41A4
41B
43A2
43A4
43B
43C
43C
45A2
45A4
45B
45B
45C
45D
45E
45F
47A2
45G
47A4
47A2
47A4
47B2
47B4
47C2
47C4
47D2
47D4
49A2
49A4
49B
51A2
51A4
51B
in.
1.500
1.500
1.500
mm
38.1
38.1
38.1
1.500
38.1
1.978
50.2
1.978
50.2
1.978
50.2
1.978
50.2
1.978
50.2
2.441
1.978
2.441
62.0
50.2
62.0
2.441
62.0
2.441
62.0
3.500
88.9
3.500
88.9
in.
3.244
3.244
3.423
3.423
3.578
3.786
3.786
4.140
4.265
4.265
4.515
4.656
4.796
4.796
5.078
5.171
5.421
5.499
5.671
5.796
5.827
5.671
5.827
5.983
6.093
6.281
6.468
6.687
6.827
7.327
7.546
7.796
8.234
8.452
8.608
mm
82.4
82.4
112.4
112.4
90.9
96.2
96.2
105.2
108.3
108.3
114.7
118.3
121.8
121.8
129.0
131.3
137.7
139.7
144.0
147.2
148.0
144.0
148.0
152.0
154.8
159.5
164.3
169.9
173.4
186.1
191.7
198.0
209.1
214.7
218.6
AL-2™ Large Bore LOK-SET Retrievable Casing Packer Product Family No. H64628
Casing
Packer
Weight 
OD
in.
X
58
mm
5-1/2
139.7
6
152.4
lb/ft
20
15.5–17
13
26
Nom ID
Size
45A2 x 2-3/8
45A4 x 2-3/8
45B x 2-3/8
45B x 2-3/8
Max Gage Ring OD
in.
mm
2.375
60.3
2.375
60.3
in.
4.562
4.656
4.796
4.796
mm
115.9
118.3
121.8
121.8
Max Diameter of
Compressed Drag Block
in.
mm
4.592
116.6
4.750
120.7
4.902
124.5
4.902
124.5
When selecting a packer for a casing weight common to two weight ranges (same OD), choose the packer size shown for the lighter of the two weight
ranges. Example: for 7-in. (177.8 mm) OD 26 lb/ft casing use packer size 47B4. Under certain circumstances the other packer size may be run, such
as when running in mixed casing strings.
Repair kits, including such items as packing elements, seal rings, etc., are available for redressing Baker Retrievable Packers. Contact your Baker Hughes
representative. Use only Baker Hughes repair parts.
Retrievable Packer Systems
HORNET Packer
Product Family No. H64682
HORNET EL Packer
Product Family No. H64683
APPLICATION
The mechanically set HORNET™ packer offers ease of operation with quarter-turn
right to set and release. Converting it for wireline-setting applications is simple
and inexpensive. The HORNET packer provides for landing in compression, tension,
or neutral positions. Every component from the jay track, to the internal bypass, to
the packing-element system and the upper slip assembly has been developed to
ensure the HORNET’s setting and releasing reliability.
The HORNET EL packer is run and set on electric line using an E-4™ (Product Family
No. H43702) with a slow-set power charge or a J™ setting tool (Product Family No.
H41371) and a special wireline adapter kit. An L-10™ type on/off seal nipple is run
on top of the packer to connect the tubing to the packer and to house a blanking
plug when the packer is used as a temporary bridge plug.
Advantages
Upper Slip Assembly:
tested across API minimum to maximum casing ID
tolerances for each specified casing weight, for setting and
releasing reliability
„„Slip-wicker configuration providing bidirectional-load support with solid
upper cone to support highest tensile loads
„„Staged-release action eliminates high-overpull requirement
„„Minimal set-down weight required to anchor slips
„„Thoroughly
Internal Bypass Seal:
bypass seal design provides sealing after unloading, under
differential pressures
„„No O-ring sealing system
„„Durable
Packing Element System:
tested to combined ratings at the API's maximum ID tolerance
„„Patented enhancements to control overboost
„„High-performance, three-piece element system
„„Fully
Lower Slip and Jay Assembly:
and drag blocks tested to maximum API tolerance ID for positive
set and ease of release
„„One-quarter-turn right setting and releasing action
„„Packoff of packing elements with applied tension or compression
„„Spacing in jay ensures opening of internal bypass, before slip releasing
action begins–important to both ease of release and safety
„„Automatically returns to running position
„„Slips
HORNET Packer
Product Family
No. H64682
HORNET EL Packer
Product Family
No. H64683
59
Retrievable Packer Systems
SPECIFICATION GUIDE
HORNET™ Packer, Product Family No. H64682 and
HORNET EL Packer, Product Family No. H64683
Casing
OD
Min ID
mm
4-1/2
114.3
5
5-1/2
5-3/4
127.0
139.7
146.1
in.
168.3
mm
in.
OD–ID
Box up x Pin Down
mm
13.5–15.1
3.752
95.3
3.904
99.2
365–191
11.6–13.5
3.853
97.9
4.069
103.4
375–191
9.5–10.5
3.996
101.5
4.154
105.5
388–191
21.4–23.2
3.943
100.2
4.220
107.2
388–191
15–18
4.195
106.6
4.486
113.9
410–191
20–23
4.578
116.3
4.868
123.6
17–20
4.696
119.3
4.976
126.4
2.375 EU 8Rd
2.375 EU 8Rd
450–193
2.375 EU 8Rd
450–237
2.875 EU 8Rd
460–193
2.375 EU 8Rd
460–237
2.875 EU 8Rd
472–193
2.375 EU 8Rd
14–17
4.819
122.4
5.090
129.3
472–237
2.875 EU 8Rd
13
4.980
126.5
5.122
130.1
486–193
2.375 EU 8Rd
19.5
4.980
126.5
5.122
130.1
486–237
2.875 EU 8Rd
550–237
2.875 EU 8Rd
550–292
3.500 EU 8Rd
560–237
2.875 EU 8Rd
560–292
3.500 EU 8Rd
573–237
2.875 EU 8Rd
573–292
3.500 EU 8Rd
28–32
6-5/8
Standard Thread
Connection
Max ID
Weight
in.
Packer
Size
24–28
5.569
5.694
141.5
144.6
5.897
6.021
149.8
152.9
20–24
5.801
147.3
6.142
156.0
35–38
5.801
147.3
6.142
156.0
29–32
5.990
152.1
6.293
159.8
573–237
2.875 EU 8Rd
7
177.8
23–29
7-5/8
193.7
6.174
156.8
6.466
164.2
591–237
591–292
3.500 EU 8Rd
600–237
2.875 EU 8Rd
600–292
3.500 EU 8Rd
17–23
6.239
158.5
6.570
166.9
618–237
2.875 EU 8Rd
42.8–47.1
6.239
158.5
6.570
166.9
618–292
3.500 EU 8Rd
33.7–39
6.510
165.4
6.882
174.8
645–237
2.875 EU 8Rd
3.500 EU 8Rd
26.4–29.7
6.781
172.2
7.129
181.1
2.875 EU 8Rd
670–237
3.500 EU 8Rd
60
Retrievable Packer Systems
SABRE Mechanical Set Retrievable Packer
Product Family No. H64668
APPLICATION
Baker Hughes introduces the SABRE™ mechanical-set retrievable packer. This
packer is a single-string retrievable packer based on the proven performance
and reliability of the Hornet packer. It is especially designed to perform reliably
in standard-pressure injection and production applications. It is a tension set or
compression set and can be landed in compression, tension, or a neutral condition.
The SABRE provides reliable performance in a retrievable packer under combined
conditions of 250°F (121.1°C) and 7,000 psi (482.6 bar) differential above or below
the packer.
Advantages
„„Ease
of operation–quarter-turn right to set, quarter-turn to right
to release
„„High-performance, three-piece element system for standard pressure
sealing and pressure reversal loads
„„Tested unplugged to 250°F (121.1°C) at 7,000 psi (482.6 bar)
differential both above and below
„„Tubing can be landed in tension, compression or neutral
„„Built in unloader with bonded seal for bypass
„„Nace flow wetted
„„Bypass opens before release of upper slips for safety and ease
of release
„„No O-rings
„„Staged loading of upper slips for ease of release
„„Reliable and rugged rocker-type lower-slip assembly
SPECIFICATION GUIDE
Casing
Max OD
Size
in.
5-1/2
7
mm
139.7
177.8
460–193
in.
mm
4.6
116.84
472–193
4.72
119.888
591–237
5.91
150.114
600–237
6
152.4
618–237
6.18
156.972
SABRE Mechanical Set
Retrievable Packer
Product Family No. H64668
61
Retrievable Packer Systems
HS Hydraulic-Set Single-String Retrievable Packer
Product Family No. H78460
APPLICATION
The HS™ is setting the standard for high-performance, single-string retrievable,
hydraulic-set shear-release packers. Its simple and reliable design provides
maximum pre-set prevention while running and has improved sealing and
retrieving reliability, metallurgy and elastomer selections it for the well
environment. Other applications include: production, injection and zonal isolation;
single-string selective completions or dual-string completions with multiple
packers; completions that require pre-set prevention while running; deviated wells
or other applications when rotation for installation or removal is not beneicial;
when it is beneicial to displace and set packers after the well is langed up. The
HS-S™ is beneicial when testing the tubing string before packer setting or to
independently set and test individual packers in multiple-packer completions and
stacked packer applications.
Advantages
„„Operationally
simple
set
„„Shear release
„„Built-in unloader and bypass, aids in releasing and retrieving
„„Hydraulic interlocking system prevents preset
„„Patented element system incorporates a “zero gap” backup system
„„All O-rings tested during assembly of packer
„„Bi-directional slips
„„Short, compact design
„„No mandrel movement during setting allows stacked-packer
applications
„„Hydraulically
Additional Information
The HS-S is the selective-set version of the HS hydraulic-set single-string packer.
Setting and retrieval is the same as the HS with the exception of an inner sleeve
that must be shifted mechanically before the packer will set. The selective-setting
mechanism prevents the packer from premature setting when high tubing-toannulus pressure differences are encountered or when tubing- pressure tests
are performed.
Accessories
A tubing-plugging device must be positioned below the packer for actuation: E™
hydraulic-trip sub (Product Family No. H79928); CMU(D)™ sliding sleeve (Product
Family Nos. H81079 and H81080) with blanking plug; low-control seating nipple
with blanking plug; hydraulic-setting devices (Product Family Nos. H46921, H79928
and H75917)
62
HS Hydraulic-Set Single-String
Retrievable Packer
Product Family No. H78460
Retrievable Packer Systems
SPECIFICATION GUIDE
HS™ Hydraulic-Set Packer Product Family No. H78460
Casing
OD
in.
Packer
Weight
Range
mm
139.7
5-1/2
lb/ft
177.8
26–29
29–32
244.5
9-5/8
Gage OD
in.
mm
450–193
1.930
49.0
450–237
2.373
60.3
608–292
2.920
74.2
15.5–23
23–26
7
Min ID
Packer
Size
608–237
2.373
60.3
608–193
1.930
49.0
598–292
2.920
74.2
598–237
2.373
60.3
598–193
1.930
49.0
591–292
2.920
74.2
591–237
2.373
60.3
591–193
1.930
49.0
831–193
1.930
49.0
831–237
2.373
60.3
831–292
2.920
74.2
831–389
3.894
98.9
40–53.5
in.
mm
4.500
114.3
6.080
154.4
5.980
150.1
5.910
150.1
8.310
211.1
NOTE: See packer rating envelopes.
HS-S™ Hydraulic-Set Packer R, Product Family NO. H78461
Casing
Weight
Range
OD
in.
Packer
mm
Min ID
Packer
Size
lb/ft
in.
mm
608–281
2.813
71.5
608–231
2.313
58.8
23–26
591–281
2.813
71.5
591–231
2.313
58.8
23–32
7
177.8
26–29
29–32
Gage OD
598–292
2.920
74.2
598–237
2.373
60.3
598–193
1.930
49.0
591–292
2.920
74.2
591–237
2.373
60.3
591–193
1.930
49.0
in.
mm
6.080
154.4
5.910
150.1
5.910
150.1
5.910
150.10
NOTE: See packer rating envelopes.
63
Retrievable Packer Systems
FH and FHL Hydrostatic-Set Single-String
Retrievable Packers
Product Family No. H78108 and H78120
APPLICATION
The FH™ is the industry-standard, hydrostatic-set and shear-release single-string
retrievable packer. It can be used in the following applications: production,
injection, and zonal isolation; single-string selective completions or dual-string
completions with multiple packers; deviated wells or other applications when
rotation for installation or removal is not beneicial; when it is beneicial to displace
and set packers after the well is langed up; when testing the tubing string before
packer setting or to independently set and test individual packers in multiplepacker completions is beneicial.
The FH packer is hydraulically activated by applying tubing pressure against a
plugging device below the packer. The packer requires only straight pull to release.
The FHL™ is the large-bore version of the FH packer. Features, advantages and
operational procedures are the same as those for the FH packers.
Advantages
„„Operationally
simple
activated, hydrostatic-set, low-pressure,
rig-pump-capable activation
„„Field-adjustable shear release
„„Built-in unloader and bypass aids in releasing and retrieving
„„Packoff is mechanically locked and constantly reinforced by
hydrostatic pressure
„„Triple-seal multi-durometer elements ensure pressure integrity over a
wide range of temperatures and conforms easily to casing irregularities
„„No mandrel movement during setting allows
stacked-packer applications
„„Hydraulically
Accessories
A tubing-plugging device must be positioned below the packer for actuation:
E™ hydraulic-trip sub (Product Family No. H79928); CMU(D)™ sliding sleeve (Product
Family Nos. H81079 and H81080) with blanking plug; Baker Hughes low-control
seating nipple with blanking plug; hydraulic-setting devices (Product Family Nos.
H46921, H79928 and H75917)
FH and FHL Hydrostatic-Set
Single-String Retrievable Packer
Product Family Nos. H78108 and H78120
64
Retrievable Packer Systems
SPECIFICATION GUIDES
FH™ HYDROSTATIC-SET SINGLE-STRING PACKER, Product Family No. H78108
Casing
OD
in.
mm
lb/ft
4-1/2
114.3
9.5–13.5
5
127.0
139.7
5-1/2
152.4
6
168.3
6-5/8
177.8
7
168.3
6-5/8
177.8
7
193.7
7-5/8
219.1
8-5/8
244.5
9-5/8

Weight 
Packer
Size
43A
Nom ID
Max Gage Ring OD
in.
mm
in.
mm
1.978
50.2
3.786
95.2
1.978
50.2
4.140
105.2
4.255
108.3
15–18
43B
11.5–15
43C
26
43C
4.255
108.3
20–23
45A2
4.515
114.7
15.5 –20
45A4
4.656
118.3
13–15.5
45B
4.796
121.8
26
45B
4.796
121.8
5.078
129.0
50.2
1.978
20–23
45C
15–18
45D
5.171
131.3
34
45E2
5.421
137.7
28–32
45E4
24–28
46A4
50.2
1.978
1.978
50.2
2.416
61.4
5.499
139.7
5.603
142.3
38
46A4
2.416
61.4
5.603
142.3
24
47A2
144.0
47A4
61.4 or
50.8
5.671
17–20
2.416 or
2.000
38
47A2
32–35
47A4
26–29
47B2
20–26
47B4
17–20
47C2
33.7–39
47C4
24–29.7
47D2
20–24
47D4
44–49
49A2
32–40
49A4
20–28
49B
47–53.5
51A2
40–47
51A4
29.3–36
51B
61.4
or
50.8
2.416
or
2.000
5.827
148.0
5.671
144.0
5.827
148.0
5.983
152.0
6.093
154.8
6.281
159.5
2.416
or
2.000
61.4
or
50.8
6.468
164.3
6.687
169.9
6.827
173.4
3.000 or
2.416 or
2.000
46.2 or
61.4 or
50.8
7.327
186.1
7.546
191.7
7.796
198.0
3.000 or
2.416 or
2.000
46.2 or
61.4 or
50.8
8.233
209.1
8.452
214.7
8.608
218.6
When selecting a packer for a casing weight common to two weight ranges (same OD), choose the packer size shown for the lighter of the two weight ranges.
Example: for 7 in. (177.8 mm) 20 lb/ft casing use packer size 47C2. Under certain circumstances the other packer size may be run, such as when running in
mixed-casing strings.
NOTE: Repair kits, including such items as packing elements, seal rings, etc., are available for redressing retrievable packers.
Contact your Baker Hughes representative. Use only genuine Baker Hughes repair parts.
FHL™ HYDROSTATIC-SET SINGLE-STRING PACKER, Product Family No. H78120
Casing
OD
in.
mm
Weight 
lb/ft
24
6-5/8
7
7-5/8
168.3
177.8
193.7

244.5
Size
in.
Max Gage Ring OD
mm
47A2
mm
5.671
144.0
47A4
5.827
148.0
17
47B2
5.983
152.0
38
47A2
5.671
144.0
32–35
47A4
5.827
148.0
26–29
47B2
5.983
152.0
20–26
47B4
6.093
154.8
17–20
47C2
6.281
159.5
6.468
164.3
6.687
169.9
33.7–39
47C4
24–29.7
47D2
20–24
47D4
51A2 x 4-3/4
3.000
3.000
3.000
76.2
in.
20
47–53.5
9-5/8
Packer
Nom ID
76.2
76.2
4.750
120.7
4.000
101.6
51A2
40–47
51A4
29.3–36
51B
6.827
173.4
8.233
209.1
8.452
214.7
8.608
218.6
When selecting a packer for a casing weight common to two weight ranges (same OD), choose the packer size shown for the lighter of the two weight ranges.
Example: for 7-in. (177.8 mm) 20 lb/ft casing use packer size 47C2. Under certain circumstances the other packer size may be run, such as when running in
mixed-casing strings.
NOTE: Repair kits, including such items as packing elements, seal rings, etc., are available for redressing retrievable packers.
Contact your Baker Hughes representative. Use only genuine Baker Hughes repair parts.
65
Retrievable Packer Systems
Premier Removable Production Packer
Product Family No. H78463, H78467, and H78468
APPLICATION
The Premier™ packer is a hydraulic-set, large-bore, removable production packer. It combines the performance
of a permanent packer with the conveniences of a retrievable packer. The Premier is ideally suited for big-bore
completions and multizone stacked-packer completions. Its retrieving options offer new alternatives in high
intervention cost applications.
Advantages
„„Slip-element-slip
design isolates element from boost loads
ID is similar to large-bore permanent packers
„„Proven high performance, tested to ISO 14310 VO requirement
„„Retrieval on production tubing by through-tubing chemical or mechanical cut or shear release
„„Retrieval on workstring by retrieving tool or milling tool
„„The patented field proven zero-extrusion back up system is designed for ease of removal
„„Positive debris barrier, protects slips from deposits and debris for ensured retrieval
„„Multiple setting options, configurable for traditional or interventionless setting
„„No body movement during setting; ideal for single- or multiple-packer completions
„„Modular design suited for threaded connections or upper sealbore
„„Optional low-pressure setting in certain sizes
„„Large
Additional Information
The Premier can be threaded directly to the production string or connected with an anchor-seal assembly.
One-trip setting is accomplished by pressuring up against a plugging device below the packer. Retrieval on the
production string is accomplished by cutting the mandrel with a chemical or mechanical cutting tool. Shift-torelease and shear-release options are available for medium-service applications.
SPECIFICATION GUIDE
Casing
OD
in.
5-1/2 l
Weight
mm
lb/ft
139.7
20–23
32–35
7
177.8
29–32
26–29
33.7–39
7-5/8
193.6
29.7–33.7
47–53.5
9-5/8
244.5
40–47
10-3/4
273.1
13-3/8
339.7
13-5/8
338.5
60.7–65.7
68
72
88
Max OD
Size
450-(36x)239
582-(47x)387
582-(47x)376
582-(36x)287
591-(47x)387
591-(47x)376
591-(36x)287
598-(47x)387
598-(47x)376
598-(36x)287
645-(47x)387
645-(47x)376
659-(47x)387
659-(47x)376
831-(60x)490
831-(60x)475
831-(47x)387
845-(60x)490
845-(60x)475
845-(47x)387
934-(73x)600
in.
mm
4.500
114.3
5.820
147.8
5.910
150.1
5.983
152.0
6.450
163.8
6.590
167.4
8.310
211.1
8.450
214.6
Packer
Optional Upper
Sealbore 
in.
mm
3.625
92.1
4.750
120.7
Min ID
Elastomers
in.
mm
60.7
98.4
95.5
72.9
98.4
95.5
72.9
98.4
95.5
72.9
98.4
95.5
98.4
95.5
124.5
120.7
98.4
124.5
120.7
98.4
155.8
3.625
92.1
4.750
120.7
3.625
92.1
4.750
120.7
6.000
155.8
4.750
120.7
6.000
155.8
4.750
7.375
120.7
187.3
2.390
3.875
3.760
2.870
3.875
3.760
2.870
3.875
3.760
2.870
3.875
3.760
3.875
3.760
4.900
4.750
3.875
4.900
4.750
3.875
6.000
6.000
155.8
4.750
120.7
3.625
92.1
4.750
120.7
Aflas™
HNBR,
Nitrile and
Aflas
HNBR,
Nitrile and
Aflas
HNBR,
Nitrile and
Aflas
HNBR,
Nitrile and
Aflas
9.345
237.3
1209x850
12.090
307.1
10.183
258.6
8.500
215.9
Nitrile
1209x850
12.090
307.1
10.183
258.6
8.500
215.9
Nitrile
934-(60x)475
When upper sealbore is used, the packer can be retrieved on the workstring using the Premier workstring retrieving tool (POWER),
Product Family No. H78464. l 5-1/2 is V3 rated.
66
Premier Removable
Production Packer
Product Family No. H78463
Retrievable Packer Systems
Premier Removable Production Packer With Striker
Product Family No. H78465
APPLICATION
The Premier™ Packer with Striker™ interventionless packer setting system is a proven
product for interventionless actuation of the Premier packer. It is the new class of
“removable” packers designed for wells that demand the sealing performance of a
permanent packer and the lexible workover options of a traditional retrievable packer.
Because the Premier can be remotely actuated, rig time/cost is reduced and risks
associated with standard well intervention setting methods, are minimized. This results in
a cost-savings beneit for the operator.
Advantages
„„Slip-element-slip
grips slips isolated from high pressure
IDs similar to large-bore permanent packer
„„High performance, tested to ISO 14310 VO requirement
„„Multiple removal on production tubing, through-tubing chemical or
mechanical cut
„„The patented field proven zero-extrusion back up system is designed for ease
of removal
„„Positive debris barrier protects slips from deposits and debris for
ensured retrieval
„„No body movement during setting, ideal for single–or multiple-packer
completions
„„Modular design; packer suited for threaded connections or upper sealbore
„„Interventionless actuation eliminates wireline, slick-line, and coiled-tubing
interventions and associated risk
„„Proven actuation systems; primary and fully-independent secondary
setting mechanisms
„„Large
Accessories
The Striker system is a device that generates packer setting force from hydrostatic well
pressure. As a secondary or contingent setting method, it can also be set by hydraulic
pressure. The Striker modular design is a derivation of the innovative and successful SB3H™ hydrostatic/hydraulic retainer production packer. It can be removed on the production
string by cutting the mandrel with a chemical or mechanical cutting tool. The Premier
system offers unique high-performance and multiple-removal options for high-cost
intervention completions.
Premier Removable
Production Packer With Striker
Product Family No. H78465
67
Retrievable Packer Systems
SC-2 Retrievable Packer
Product Family No. H48807
APPLICATION
The Baker Hughes SC-2™ retrievable packer is a high-performance, retrievable,
sealbore packer. It can be run and set on electric wireline, slick line/tubing with
the same setting tools used for the D packer.
Advantages
„„Can
be set with wireline or hydraulic setting tools
be equipped with a variety of bottom guides (must be
ordered separately)
„„Packer easily accommodates tubing expansion or contraction
„„Tubing and seals can be removed without accidentally unsetting packer
„„Easy retrieval due to caged slips and releasing mechanism located in
protected area below packing element
„„Packer’s releasing mechanism is not affected by differential pressure
or tailpipe weight
„„Case-hardened slips suitable for all grades of casing including V-150
„„Compatible with standard Baker Hughes’ seal accessories, tubingconveyed perforating and gravel-packing systems
„„Can
SC-2 Retrievable Packer
Product Family No. H48807
68
Retrievable Packer Systems
SPECIFICATION GUIDE
SC-2™ Retrievable Packer, Product Family No. H48807
Packer 
Casing
T&C
Weight ▼
OD
Max Gage Ring OD
Size l
in.
mm
lb/ft
20–23
55A2–26
4.485
113.9
4.406
111.9
5-1/2
139.7
17–20
55A4–26
4.593
116.6
4.500
114.3
177.8
7
in.
Max Packing Element
55B–26
4.765
121.0
4.687
119.0
7OA2–32
5.735
145.6
5.687
144.4
29–32
7OA4–32
5.820
147.8
5.750
146.0
23–29
7OB–32
6.000
152.4
5.937
150.8
6.250
158.7
6.187
157.1
76A2–32 ◆
76A2–40 ◆
6.440
163.6
6.375
161.9
◆
◆
7OC–32
6.580
167.1
6.500
165.1
24–29.7
76B2–32 ◆
76B2–40 ◆
6.690
169.9
6.625
168.2
20–24
76B4–32 ◆
76B4–40 ◆
6.784
172.3
6.718
170.6
8.191
208.0
8.125
206.3
29.7–33.7
76A4–32
53.5–58.4
244.4
9-5/8
mm
35–38
17–20
193.6
in.
13–15.5
33.7–39
7-5/8
mm
76A4–40
96A–47
47–53.5
96A2–47
8.319
211.3
8.250
209.5
40–47
96A4–47
8.465
215.0
8.375
212.7
36–40
96B–47
8.619
218.9
8.500
215.9
Sealbore Dia for Seal Nipples n
in.
mm
Seal
Accessory
Size ▲
in.
mm
2.688
68.2
40–26
1.968
50.0
3.250
82.5
80–32 or 81–32
2.406 or 1.995
61.1 or 50.6
76A2–40
4.000
101.6
80–40
3.000
72.6
76A4–32
3.250
82.5
80–32 or 81–32
2.406 or 1.995
61.1 or 50.6
76A4–40
4.000
101.6
80–40
3.000
72.6
76B2–32
3.250
82.5
80–32 or 81–32
2.406 or 1.995
61.1 or 50.6
Size
Min Bore Thru Seal Nipples
55A2–26
55A4–26
55B–26
7OA2–32
7OA4–32
7OB–32
7OC–32
76A2–32
76B2–40
4.000
101.6
80–40
3.000
72.6
76B4–32
3.250
82.5
80–32 or 81–32
2.406 or 1.995
61.1 or 50.6
76B4–40
4.000
101.6
80–40
3.000
72.6
4.750
120.6
190–47 or 192–47
3.000 or 3.875
72.6 or 98.4
96A–47
96A2–47
96A4–47
96B–47
X
For information on packer or accessory sizes not found in this specification guide, refer to Baker Hughes' packer systems technical manual or your
Baker Hughes representative.
l When proposed for use in other than the casing weight range shown, contact your Baker Hughes representative.
n The maximum OD (including tolerance) of any part run through a production packer should be at least 1/16-in. (1.59mm) smaller than the minimum bore through the
packer body. This may occasionally require that the coupling ODs be turned down.
▲ Tubing-seal assemblies, tubing seal and spacer nipples.
◆ This tool available with 3.250 in. (82.5 mm) or 4.000 in. (101.6 mm) seal bore diameter and uses sizes 80-32/ 81–32 or 80–40 accessories respectively.
▼ When selecting a SC-2 packer for a casing weight common to two size packers choose the packer with the smallest OD to maximize running clearances.
Example: In 5-1/2-in. (139.7-mm), 20.0-lb/ft casing, use size 55A2–26.
69
Retrievable Packer Systems
Reliant Series WL Wireline-Set
Single-String Retrievable Packer
Product Family Nos. H64710 (Standard Service) and H64711 (S&R:NACE Service)
APPLICATION
The WL™packer is a new wireline-set, retrievable, high-performance production packer, run in combination
with the L-10 on/off tool. The WL can be run as a temporary bridge plug by installing a blanking plug in the
L-10 seal nipple, above the packer. This enables remedial or stimulation work above the packer. The plug can
then be removed with conventional wireline methods, allowing production of the well to be resumed.
SPECIFICATION GUIDE
Casing
OD
in.
Packer
Weight
Range
mm
lb/ft
13.5–15.1
4-1/2
5
5-1/2
114.3
127.0
139.7
Max OD
365–188
in.
mm
3.650
92.7
11.6–13.5
375–188
3.750
95.3
9.5–11.6
384–188
3.840
97.5
21.4–23.2
384–188
3.840
97.5
15–18
410–188
4.100
104.1
4.500
114.3
450–193
15.5–23
450–237
7
177.8
35–38
573–237
5.730
145.5
26–32
591–237
5.910
150.1
23–26
608–237
6.080
154.4
6.450
163.8
645–237
33.7–39.0
7-5/8
193.7
Threads EU
(Box x Pin)
Min ID
Size
in.
mm
in.
mm
1.885
47.9
2-3/8
60.3
1.885
47.9
2-3/8
60.3
1.930
49.0
2-3/8
60.3
2.373
60.3
2-7/8
73.0
2.373
60.3
2-7/8
73.0
2.373
60.3
2-7/8
73.0
645–292
2.919
74.1
3-1/2
88.9
659–237
2.373
60.3
2-7/8
73.0
2.922
74.2
3-1/2
88.9
26.4–33.7
6.590
659–292
167.4
Reliant Series
WL Wireline-Set Single-String
Retrievable Packer
Product Family No. H64710
70
Retrievable Packer Systems
MJS Thermal Packer
Product Family No. H41754
APPLICATION
The MJS™ packer is a compact, high-performance, thermal packer system which offers an expansion joint
and a casing packer in a single assembly. The MJS is a rotationally set, double-grip packer, speciically
designed for use in steam injection, huff and puff or geothermal production wells, when a wide range of
pressures from above or below are anticipated.
Advantages
„„Rated
for 2,800 psi (19.2 MPa) differential pressure at 680°F (360°C)
design is well suited for annulus pressure testing applications
„„Integral expansion joint’s 15- and 20-ft mandrel lengths allow tubing expansion and eliminate the
need for additional equipment to be run above the packer
„„Mandrels of other lengths are available upon special request
„„Packer sets easily using right-hand rotation in deep or shallow wells
„„Releases with tension and offers a “soft shear” feature, which reduces tubing stretch and re-coil
during shear out, making it ideal for use with insulated tubing or the longer strings of
deep-injection wells
„„Shear release force is adjustable
„„Double-grip
Additional Information
Please note: Tubing weight and grade must be capable of applying minimum speciied setting torque
to the packer.
SPECIFICATION GUIDE
Casing
OD
in.
4-1/2
5
5-1/2
6-5/8
7
7-5/8
8-5/8
9-5/8
Nominal ID
Weight
mm
114.3
127.0
139.7
168.2
177.8
193.6
219.0
244.4
Packer
Size
lb/ft
Non-Insulated
Mandrel
in.
13.5–15.1
43A
9.5–11.6
43A4
1.50
15–18
43B2
11.5–13
43B4
2.0
20
45A2
13–17
45A4
28–32
46A2
20–24
46A4
29–32
47A2
23–26
47B4
1.94
2.50
3.00
mm
38.1
50.8
49.2
50.8
76.2
Insulated
Mandrel
in.
-
-
-
mm
Max Gage
Ring OD
in.
mm
3.687
93.7
3.781
96.1
4.125
104.8
4.250
108.0
4.594
116.7
4.687
119.1
-
-
1.995
50.7
5.465
138.9
2.441
62.0
5.718
145.3
5.875
149.3
2.441
62.0
6.062
154.0
17–20
47C2
6.250
159.8
33.7–39
47C4
6.406
162.8
26.4–29.7
47D2
20–24
47D4
44–49
49A2
36–40
49A4
24–32
49B
43.5–47
51A2
3.50
4.50
4.875
36–40
51A4
88.9
114.3
123.9
-
3.068
3.068
-
78.0
6.656
169.1
6.812
173.1
7.343
186.6
7.515
190.9
7.750
196.9
8.438
214.4
78.0
8.593
218.3
Stroke
ft
m
15 and 20
4.6 and 6.1
15 and 20
4.6 and 6.1
15 and 20
4.6 and 6.1
15 and 20
4.6 and 6.1
15 and 20
4.6 and 6.1
15 and 20
4.6 and 6.1
15 and 20
4.6 and 6.1
15 and 20
4.6 and 6.1
MJS Thermal Packer
Product Family No. H41754
71
Retrievable Packer Systems
GT Dual-String Retrievable Packer
Product Family Nos. H78509 (Standard Service)
and H78510 (NACE Service)
APPLICATION
The GT™ is the standard for high-performance, dual-string,
retrievable, hydraulic-set and shear-release packers. It offers
maximum pre-set prevention while running and has improved
sealing and retrieving reliability and the utmost lexibility
in custom applications. The simple and reliable design
incorporates a versatile packing element system that is ideally
suited for high-pressure gas wells.
Additional GT Applications
„„Production,
injection, and zonal isolation
an upper packer when the bottom packer is a single-bore
packer or as the upper or intermediate packer in tandem or
selective-tandem dual completions
„„Horizontal, extended-reach, or other completions when
maximum pre-set prevention while running is preferred
„„Deviated wells or other applications when no rotation for
installation or removal is wanted
„„When there is a need to displace and set the packers after
the well is flanged up
„„With selective-set versions, applications when it is
preferable to test the tubing string before packer setting or
to independently set and test individual packers in multiplepacker completions
„„As
Additional Information
The GT-S™ is the selective-set version of the GT. Setting
and retrieval is the same as the GT with the exception of an
inner sleeve that must be shifted before the packer will set.
The selective-set optional module prevents the packer from
premature setting when high tubing-to-annulus pressure
differentials are encountered or when tubing-pressure tests
are performed.
Advantages
„„Operationally
simple; install and retrieve
multiple packers on the production
string without tubing manipulation or
well intervention
„„Hydraulically set
„„Shear release allows packer to be
released by simply pulling on either
tubing string
„„Built-in bypass aids in releasing
and retrieving
„„Hydraulic interlocking system prevents
preset, all components are mechanically
locked to mandrel during run-in
„„Reliable performance; defined
by performance envelopes which
graphically describe simultaneous
effects of load and pressure
„„Patented element system incorporates a
“zero gap” backup system
„„Superior O-ring and backup design allow
testing of all O-rings during assembly
of packer
„„Bi-directional slip eliminates extra leak
paths associated with hydraulic holddown buttons
„„Unique arrangement of shear rings
improves retrieving reliability
and flexibility
„„Short, compact design
„„No mandrel movement during setting
allows stacked-packer applications
„„Selective setting achieved by adding a
selective setting module with
minimal effort
Options
Packer can be conigured for short-string removal: GT DSR with parallel head, short string set, Product Family
No. H78511; GT DSR with parallel head, long string set, Product Family No. H78512
Accessories
Parallel head with snap latch or anchor latch seal assembly, Product Family Nos. H70032, H70703 and
H70711; selective head and seal nipple, Product Family Nos. H78351 and H70373
To facilitate making tubing connections and to aid with space-out: adjustable and telescoping subs,
Product Family Nos. H44120 and H44125
72
GT Dual-String Retrievable Packer
Product Family No. H78509
Retrievable Packer Systems
SPECIFICATION GUIDES
GT™ Hydraulic-Set Dual-String Packer, Product Family Nos. H78509 AND H78510
Casing
Packer
Nom ID
OD
in.
7
7-5/8
9-5/8
Max Gage OD
Weight
Range
Size
26–32
47C2
20–26
33.7–39
mm
177.8
193.7
244.5
Non-Ported
in.
Ported
mm
in.
mm
5.937
150.8
47C4
6.120
155.4
47D2
6.470
164.3
49.3
1.939
49.3
1.939
in.
1.939
1.939
mm
49.3
49.3
26.4–33.7
47D4
6.625
168.3
47–53.5
51A
8.350
212.1
40–47
51B
8.500
215.9
74.7
2.939
2.939
74.7
GT With Parallel Head, Product Family No. H78515
Packer Size
Min Bore Thru Seal Nipple
in.
in.
mm
47C2 2-3/8 x 2.68
1.968
50.0
47C4 2-3/8 x 2.68
1.968
50.0
47D2 2-3/8 x 2.68
1.968
50.0
47D4 2-3/8 x 2.68
1.968
50.0
51A 3-1/2 x 3.25
2.375
60.3
51A 3-1/2 x 3.75
3.000
76.2
51B 3-1/2 x 3.25
2.375
60.3
51B 3-1/2 x 3.75
3.000
76.2
Parallel Head
Product Family No. H70032
APPLICATION
The Baker Hughes parallel head assembly for the GT dual-string packer comprises a scoophead,
sealbore receptacle, and other components needed to modify the standard pin x-pin packer into a
short-or long-string set coniguration. This module allows independent running of the short string
above the packer. This module may also be recommended when retrieval of the short string,
without releasing the packer, is necessary during the life of the completion.
Parallel Head
Product Family No. H70032
73
Retrievable Packer Systems
A-5 Dual-String Retrievable Packer
Product Family Nos. H78316, H78330 and H78331
APPLICATION
The A-5™ is the industry-standard, hydrostatic-set and shear-release, dual-string retrievable packer, which
can be used in a number of applications:
„„Production,
injection and zonal isolation
„„As an upper packer when the bottom packer is a single-bore packer or as the upper or intermediate packer
in tandem or selective-tandem dual completions
„„For deviated wells or other applications when no rotation for installation or removal is preferred
„„When displacing and setting the packers after the well is flanged up is preferred
Advantages
„„Operationally
simple; multiple packers on production string can be installed and retrieved without
tubing manipulation or well intervention:
„„Hydraulically activated, hydrostatic set: low-pressure, rig-pump-capable activation
„„Shear-release packer released by simply pulling on the tubing string
„„Built-in bypass aids in releasing and retrieving
„„Packoff constantly reinforced by hydrostatic pressure and is mechanically locked
„„Triple-seal multi-durometer elements ensure pressure integrity over a wide range of temperatures
and conform easily to casing irregularities
„„No mandrel movement during setting allows stacked-packer applications
Additional Information
The A-5 packer is hydraulically activated for hydrostatic setting by applying low-tubing pressure against
a plugging device, below the packer in the short string. A straight pull against the long string is all that’s
required to release the packer.
Accessories
Short-string seal assemblies or accessories to remove the long string as well: snap latch or anchor latch seal
assembly (Product Family Nos. H70032, H70703 and H70711); selective head and seal nipple
(Product Family Nos. H78351 and H70373)
A tubing-plugging device must be positioned below the packer for actuation:
E™ hydraulic-trip sub (Product Family No. H79928); CMU(D)™ sliding sleeve (Product Family Nos. H81079 and
H81080) with blanking plug; low-control seating nipple with blanking plug; hydraulic-setting devices (Product
Family Nos. H46921, H79928 and H75917)
To facilitate making tubing connections and to aid with space out: adjustable and telescoping subs (Product
Family Nos. H44120 and H44125)
A-5 Dual-String
Retrievable Packer
Product Family No. H78316
74
Retrievable Packer Systems
SPECIFICATION GUIDE
A-5™ and AL-5™ Long-String Hydrostatic Dual-String Retrievable Packer, Product Family No. H78316
Packer
Casing
OD
in.
Weight
mm
5-1/2
139.7
6
152.4
6-5/8
Long String
168.2
in.
mm
20–23
lb/ft
45A (1.900 x 2.06)
4.500
114.3
14–17
45B (1.900 x 2.06)
4.641
117.8
15–23
45C (1.900 x 2.06)
5.062
128.5
32
46A (2-3/8 x 2.28)
5.437
138.1
24–28
46B2 (2-3/8 x 2.28)
5.625
142.8
20–24
46B3 (2-3/8 x 2.28)
5.750
146.0
20
46B4 (2-3/8 x 2.28)
5.812
147.6
17
47C2 (2-3/8 x 2.28)
5.937
150.8
38
46B2 (2-3/8 x 2.28)
5.625
142.8
35–38
46B3 (2-3/8 x 2.28)
5.750
146.0
35
46B4 (2-3/8 x 2.28)
5.812
147.6
5.937
150.8
23–32
7
Size
Max Gage and
Guide Ring OD
177.8
47C2 (2-7/8 x 2.28)
47C2 (2-3/8 x 2.68)
47C4 (2-7/8 x 2.28)
20–26
47C4 (2-3/8 x 2.68)
6.093
154.8
6.266
159.2
6.453
163.9
47C4 (2-3/8 x 2.28)
47C6 (2-7/8 x 2.28)
17–20
47C6 (2-3/8 x 2.68)
47C6 (2-3/8 x 2.28)
47D2 (2-7/8 x 2.28)
33.7–39
7-5/8
47D2 (2-3/8 x 2.68)
47D2 (2-3/8 x 2.28)
48A (2-7/8 x 2.68)
193.6
6.463
164.2
47D4 (2-7/8 x 2.28)
47D4 (2-3/8 x 2.68)
6.672
169.5
49A (2-7/8 x 3.25)
7.250
184.1
36–40
49B (2-7/8 x 3.25)
7.437
188.9
24–32
49C (2-7/8 x 3.25)
7.687
195.2
53.5
51A (3-1/2 x 3.25)
8.312
211.1
24–29.7
47D4 (2-3/8 x 2.28)
48B (2-7/8 x 2.68)
44–49
8-5/8
219.0
Nom ID
Thru Packer
in.
mm
in.
mm
in.
mm
1.562
39.7
1.562
39.7
1.531
38.6
2.06
1.562
39.7
1.562
39.7
1.531
38.6
2.06
1.938
49.2
1.562
39.7
1.625
41.3
2.28
1.938
49.2
1.562
39.7
1.625
41.3
2.28
1.938
49.2
2.438
61.9
49.2
1.938
49.2
1.970 (Size 2.68)
50.0
2.68
2.438
61.9
1.562
39.7
1.625
41.3
2.28
1.938
49.2
1.938
49.2
1.625 (Size 2.28) or
1.970 (Size 2.68)
41.3 or
50.0
2.28 or 2.68
2.438
61.9
1.562
39.7
1.625
41.3
2.28
1.625 (Size 2.28) or
1.970 (Size 2.68)
41.3 or
50.0
2.28 or 2.68
1.938
49.2
1.938
49.2
2.438
61.9
1.562
39.7
1.625
41.3
2.28
1.938
49.2
1.625 (Size 2.28) or
1.970 (Size 2.68)
41.3 or
50.0
2.28 or 2.68
1.970
50.0
2.68
1.562
39.7
1.625
41.3
2.28
49.2
1.625 (Size 2.28) or
1.970 (Size 2.68)
41.3 or
50.0
2.28 or 2.68
1.970
50.0
2.68
2.375
60.3
3.25
1.938
49.2
2.375
60.3
2.438
61.9
1.938
49.2
2.375
60.3
2.438
61.9
3.000
76.2
51B (3-1/2 x 3.75)
40–47
51B (3-1/2 x 3.25)
8.500
215.9
51B (3-1/2 x 2.68)
3.000
51C (3-1/2 x 3.75)
29.3–36
51C (3-1/2 x 3.25)
51C (3-1/2 x 2.68)
8.687
220.6
Seal
Nipple
Size
1.938
51A (3-1/2 x 2.68)
244.4
Min Bore
Thru Seal Nipple
Product Family
No. H70703
Nom ID Thru
Packer
51A (3-1/2 x 3.75)
9-5/8
Short String
76.2
1.938
2.438
61.9
3.000
76.2
2.000
50.8
3.000
76.2
2.000
50.8
3.000
76.2
2.000
50.8
3.000
76.2
3.75
2.375
60.3
3.25
1.970
50.0
2.68
3.000
76.2
3.75
2.375
60.3
3.25
1.970
50.0
2.68
3.000
76.2
3.75
2.375
60.3
3.25
1.970
50.0
2.68
75
Retrievable Packer Systems
Twin Seal Electric Submersible Pump Packer
Product Family No. H78540
APPLICATION
The Twin Seal™ packer is a ield-proven, high-performance packer specially
designed for deployment of electric submersible pumps.
Advantages
„„High-performance
rating: 5,000 psi and 275°F (135°C)
packing elements protect slip system from debris, easing
packer release
„„Reliable hydraulic-setting mechanism simplifies running procedures
„„Packer can be spaced out in neutral, compression or tension, providing
completion flexibility
„„Full-bore production mandrel reduces flow restrictions in
high-volume wells
„„Control-line setting option available by special order
„„Coiled-tubing-deployed version available
„„Twin
Additional Information
The packer is provided with a large-bore production mandrel and an electricalcable feed-through that is adaptable to popular cable packoff systems. And, there
are two smaller feed-throughs that may be used for an annular-gas vent valve
and instrumentation and chemical-injection lines. There is no relative movement
between the strings when setting or releasing the packer, eliminating unwanted
cable strain.
The packer is set with hydraulic pressure and has a straight-pull release. The twin
packing elements, above and below the slips, enable the packer to maintain the
same pressure rating from either direction.
Twin Seal Electric
Submersible Pump Packer
Product Family No. H78540
76
SPECIFICATION GUIDE
Twin Seal™ Electrical Submersible Pump Packer, Product Family No. H78540
Casing
Casing
in.
7
mm
177.8
Packer
Weight
Packer
Size
lb/ft
Max Gage
Ring OD
in.
mm
29–32
47C2
5.943
150.9
26–29
47C4
6.000
152.4
23–26
47C6
6.109
155.1
20–23
47C8
6.203
157.5
17–20
47C10
6.250
158.7
33.7–39
48D2
6.438
163.5
29.7–33.7
48D4
6.562
166.6
in.
mm
5.938
150.8
6.094
6.375
7-5/8
48D6
6.703
170.2
24–26.4
48D8
6.796
172.6
44–49
49A2
7.312
185.7
X
219.0
244.4
With BIW
Penetrator
Less BIW
Penetrator
2-3/8 x PEN
2-3/8 x 2-3/8
2-7/8 x PEN
36–40
49A4
7.546
191.6
53.5–58.4
51A2
8.265
209.9
47–53.5
51A4
8.328
211.5
43.5–47
51A6
8.453
214.7
40–43.5
51A8
8.500
216.2
36–40
51A10
8.594
218.2
in.
mm
1.922
48.8
2.375
2-7/8 x 2-3/8
2.441
189.0
8.203
208.3
2-7/8 x PEN
4-1/2 x PEN
212.3
2-7/8 x 1.900
2.441
4-1/2 x 2-3/8
3.860
or
3-1/2 x 3-1/2 l
Std Thd
Box x Pin ▲
With BIW Pen
Volt/AMP
4 KV / 100 AMP
62.0
2-7/8 EU 8 Rd
x
2-7/8 NU 10 Rd
4 KV / 100 AMP
62.0
2-7/8 EU 8 Rd
x
2-7/8 NU 10 Rd
98.0
4-1/2 LTC
x
4-1/2 LTC
60.3
Optional Vent Tubes l
Secondary String
2-3/8 EU 8 Rd
x
2-3/8 NU 10 Rd
or
2-7/8 NU 10 Rd
x
2-7/8 NU 10 Rd
169.0
7.411
8.359
2-7/8 x 1.900
Min ID
161.9
2-7/8 x PEN
26.4–29.7
Production Tubing String
4 KV / 125 AMP
4 KV / 125 AMP
Available only on packers which are equipped with drop-in penetrators or cable feed-through.
l Optional feature, suppled on special request only.
▲ Threads shown before are "standard" for the respective packer sizes. Other threads are available on request. Please specify thread when ordering.
n Contact your Baker Hughes representative for information concerning these alternate size configurations.
NOTE: Repair kits, including such items as packing elements, seal rings, etc., are available for redressing retrievable packers.
Contact your Baker Hughes representative. Use only Baker Hughes repair kits.
Less BIW Penetrator
Min ID
in.
2.062
1.521
2.062
1.521
2.015
1.521
2.015
Max
Qty.
Nom ID
Std Thd
Box x Pin
Optional
Bypass Gas
l
Std Box
Up
mm
Box x Pin ▲
52.3
38.6
2-3/8 NU 10 Rd
x
2-3/8 NU 10 Rd
or
1.900 NU 10 Rd
x
1.900 NU 10 Rd
2
52.3
2-3/8 NU 10 Rd
x
2-3/8 NU 10 Rd
2
.750
19.0
3/4 NPT
1-1/4 NPT
38.6
51.1
1.900 NU 10 Rd
x
1.900 NU 10 Rd
2-3/8 EU 8 Rd
x
2-3/8 NU 10 Rd
3
1.000 25.4
1.00 NPT
1-1/4 NPT
38.6
51.1
1.900 NU 10 Rd
x
1.900 NU 10 Rd
2-3/8 EU 8 Rd
x
2-3/8 NU 10 Rd
3
1.000 25.4
1.00 NPT
1-1/4 NPT
in.
mm
n
.750
19.0
3/4 NPT
1-1/4 NPT
77
Retrievable Packer Systems
9-5/8
154.7
193.6
6.656
8-5/8
Size
Max Packing
Element
Retrievable Packer Systems
ElecPak Electric Submersible Pump Packer
Product Family No. H78570
APPLICATION
ElecPak™ is designed to facilitate the use of an electric submersible pump.
The packer allows for the incorporation of an integral electric cable penetrator
or a feed-through drop-in penetrator system. The innovative design provides
a multiple-port coniguration for venting annular pressure, luid injection and
instrument wire access.
Advantages
„„Innovative
design optimizes multiple penetrations for venting annular
pressure, fluid injection and instrument wire access
„„Proven slip-element-slip design using metal backup system offers
optimum differential performance
„„Accepts industry-standard feed-through, drop-in penetrators or molded
integral penetrator systems
„„No relative movement between the tubing and electric cable to eliminate
cable strain
„„Simple operation: hydraulic-set, mechanically locked and straight-pull
shear release
„„Adjustable start-to-set pressure and shear-release values
„„API ISO 14310 V-3 qualified
„„Packing element flexibility: standard nitrile packing elements with
optional HNBR/FEPM
„„Multiple metallurgy options to meet downhole flow wetted requirements
SPECIFICATION GUIDE
Casing
OD
Packer Size
Weight
in.
mm
5-3/4
146.1
6-5/8
168.3
9-5/8
244.5

n
562–197
40-47
47-53.5
X
472–197
23.59-27.69 
845–370
831–292
n
Russian Casing–does not cover an API weight ID Range
In Development
NOTE: For feed-through configurations, contact your Baker Hughes representative.
ElecPak Electric
Submersible Pump Packer
Product Family No. H78570
78
Retrievable Packer Systems
Mudline Tubing Hanger
Product Family No. H79101
APPLICATION
The Baker Hughes mudline tubing hanger (MLTH) is used to manage riser/vessel
loading for offshore completions. It is designed to handle the extremely high-tensile
loads that unsupported casing is subjected to when used in deepwater completions,
on tension leg platforms.
Advantages
„„Easily
set with control line
resetting feature
„„Shear released/cut-to-release
„„Extremely high tubing tension capabilities
„„Fluid displacement feature available
„„Multiple control line bypass capability for chemical injection, TEC and/or
SCSSV control lines
„„Slip design for symmetrical loading of unsupported casing
„„Control-line bypass between slips; no feed-throughs or splices necessary
„„Multi-use
Additional Information
The MLTH is set with control line and incorporates a special multi-use re-setting
feature, which allows the MLTH to be repositioned in order to improve tubing spaceout. Once the correct setting location has been achieved, a inal pressure application
to a higher, pre-determined value will lock the MLTH into the set position. If ordered
with a burst-disc option, further pressure increase will burst the disc, permitting
well displacement above the MLTH.
SPECIFICATION GUIDE
Casing
OD
X
Weight
Size
Max
Gage Ring OD
Min ID through
L.S. Body
Max Hanging
Weight 
Max Casing
Pressure
in.
mm
lb/ft
in.
mm
in.
mm
lb
kg
PSI
bar
7
177.8
32–38
47A
5.695
144.6
2.912
73.9
300,000
136.000
8,000
550
7-5/8
193.6
29.7–39
47D
6.400
162.5
2.912
73.9
250,000
113.000
8,000
550
8-5/8
219.0
40–44
49A
7.300
185.0
3.853
98.0
130,000
58.900
8,000
550
9-5/8
244.0
47–53
51A
8.38
213.0
3.680
93.0
300,000
136.000
5,000
345
9-7/8
251.0
62.8
51A
8.38
213.0
3.680
93.0
350,000
158.700
8,000
550
10-3/4
273.0
60.7
53
9.400
238.7
4.578
116.3
500,000
226.000
8,000
550
Maximum hanging weight is dependent upon casing grade, weight and casing pressure
Mudline Tubing Hanger
Product Family No. H79101
79
Retrievable Packer Systems
FLX Packoff Tubing Hanger
Product Family No. H79080 and H79085
APPLICATION
The Baker Hughes FLX™ Packoff tubing hanger (POTH) with multiple feedthrough
penetrations is a double-grip retrievable packer designed to anchor the tubing
string in the casing at a point below the wellhead. The FLX POTH seals the area
between the casing ID and tubing OD. The FLX can withstand considerable tensile
or compressive loads from above and below and thus can be used in a variety of
completions where a second controllable annular barrier is required.
Advantages
„„Field-proven
element and slips
redundant wellhead or annulus protection system capability
„„High-tubing tension capability
„„No body movement
„„Multiple feed-through for chemical injection, TEC, and control lines
„„Suitable for multiple thermal cycles
„„Available in single and dual bore
„„Fitted with up to eight internally and externally tested
feed-through fittings
„„Available in 9-5/8-in. (244.5-mm) and 10-3/4-in. (273.1-mm) sizes
„„High-pressure versions available
„„Contingency retrieval methods available
„„Offers
Additional Information
The bi-directional slip design used in the FLX POTH has been thoroughly ield-proven
on FLEX-LOCK™ linger hanger systems and features large, evenly spaced casing
contact for use in unsupported production casing. These features minimize casing
stress levels and allow the hanger to support high combined axial and hydraulic
loads. Custom features may be incorporated to satisfy speciic requirements, such
as: one- or two-trip set, annulus or tubing set, multiple i-Wire™ bypass, chemical
injection line bypass, top end workover facility, concentric or poppet annular safety
valve and dual-bore capability.
Baker Hughes has developed a comprehensive subsurface annulus safety system
(SASS) capable of acting as a secondary subsurface wellhead. The SASS shuts in
the annulus and tubing low should a disaster at the surface result in loss of the
wellhead. Commonly, the SASS comprises of a packoff tubing hanger, annulus safety
valve, tubing safety valve, concentric tubing anchor and calibrated tensile safety joint.
Contact your local Baker Hughes representative for performance ratings.
FLX Pack-Off Tubing Hanger
Product Family
Nos. H79080 and H79085
80
Retrievable Packer Systems
ACCESSORIES SELECTION CHART
Permanent
Retrievable
Dual
Casing Cleanup Systems
x
x
x
Packer Setting Systems
x
x
Packer Retrieving Systems
x
Seal Assemblies
x
Seal Expansion/Disconnect Devices
x
Disconnect Devices
Expansion Joints
x
x
x
x
Spacing Devices
x
x
Multi-String Sealing Accessories
x
Safety Joints
x
Parallel Flow Systems
x
x
Plugging Devices
x
x
Packer Extensions
x
x
Production String Accessories
x
x
x
x
x
81
Casing Cleanup Systems
Casing Scraper
Product Family No. H16105
APPLICATION
The casing scraper is used to remove mud or cement sheath, perforation burrs, rust,
mill scale, parafin, and similar substances from the inside walls of the casing.
Advantages
„„Carburized
scraping edges on the blades provide endurance and
maximum service
„„Cleaning can be accomplished by rotation or reciprocation as a result of
blade arrangement in the body that provides 360° contact with the
casing ID
„„Each blade is cut with left-hand helical grooves, allowing tools to scrape
down inside the casing
„„Blades are secured by blade keepers which are also held by keepers for
double protection downhole
„„High-pressure versions available
„„Contingency retrieval methods available
Additional Information
Use of a casing scraper is strongly recommended before running and setting
production packers in all well conditions.
H Wireline Feeler and Junk Catcher
Product Family No. H43901
APPLICATION
The H™ wireline feeler and junk catcher is run into the well on electric line before
running the packer to ensure that the wellbore is large enough to permit subsequent
passage of the packer. The tool also serves to clean the well of debris that might foul
the packer and cause premature setting. It is suggested that a casing scraper run be
made under all well conditions before setting a packer.
Casing Scraper
Product Family No. H16105
82
H Wireline Feeler
and Junk Catcher
Product Family No. H43901
Packer Setting Systems
E-4 Wireline Pressure Setting Assembly
Product Family No. H43702
APPLICATION
The venerable E-4™ wireline pressure setting assembly is the industry standard
for wireline setting equipment. This tool is used to set wireline-set packers. In all
applications where an E-4 is used, a B™ or other appropriate wireline adapter kit will
be required. The equipment and skilled services of a licensed wireline perforating and
logging service company are also required.
The following setting procedure is typical: The proper-size wireline adapter kit
is installed in the packer. The packer and adapter kit are then connected to the
pressure setting assembly. These are run to setting depth on the electric wireline. A
small charge of electrical current, transmitted through the electric wireline, ignites
the power charge in the setting assembly, gradually building up gas pressure.
This pressure provides the controlled force necessary to set the packer. When the
prescribed setting force has been applied to the packer, the release stud in the
wireline adapter kit separates, thereby freeing the setting equipment from the packer,
allowing it to be retrieved.
The E-4 wireline pressure setting assembly is recommended for use at temperatures
below 400°F (204°C). Use of the slow-set power charge (Product Family No. H43766)
is recommended when setting permanent or retrievable packers using #10 or #20 size
E-4 wireline pressure setting assemblies.
E-4 Wireline Pressure
Setting Assembly
Product Family No. H43702
83
Packer Setting Systems
E-5 HP/HT Wireline Pressure Setting Assembly
Product Family No. H43706
APPLICATION
The E-5 HP/HT™ wireline pressure setting assembly (WLPSA) is a setting device in
which the products of combustion are used for gradual development of force through
pressure. This motive force operates the various working parts of the WLPSA in a
proper sequence to ensure the successful setting of Baker Hughes bridge plugs,
production packers, cement retainers and other products to be deployed on wireline.
The E-5 HP/HT wireline pressure-setting assembly incorporates a piercing disk
bleeder system to provide a safe, easy method of bleeding off trapped pressure
before disassembling the WLPSA after it has been run.
Advantages
„„Used
to set Baker Hughes bridge plugs, cement
retainers, and production packers on electric wireline
„„Used in conjunction with a casing collar locator for correlation of exact
setting depth
„„Uses the advantage of the fast running capability of wireline
„„Proven design has been the “Industry Standard” for many years
„„Temperature rating 450°F (232.2°C)
„„Pressure rating 25,000 psi (1 723.6 bar)
„„High-performance sealing O-rings with backup support
„„Self-contained firing head built into the HP/HT WLPSA
„„Primary, secondary, and tertiary bleed-off methods for added safety
„„Corrosion-resistance piston mandrel
„„Ability to verify conductivity of firing head on location
E-5 HP/HT Wireline Pressure
Setting Assembly
Product Family No. H43706
84
Packer Setting Systems
J and B-2 Hydraulic Setting Tools
Product Family Nos. H41371 and H41574
APPLICATION
Baker Hughes D™ and DA™, F-1™, FA-1™, HE™ and HEA™ and SC-2™ and their
respective B versions DB™ and DAB™, can be set on tubing or drillpipe using a B™
wireline adapter kit and a J™ hydraulic setting assembly. These setting assemblies
are particularly useful for setting permanent packers in high-angle, deviated wells
such as those drilled offshore.
The J hydraulic setting assembly and packer are run to setting depth on the tubing
string and a ball is dropped to the ball seat in the setting tool. Suficient tubing
pressure is then applied to set and pack off the packer. The pressure or combined
pressure and tubing tension, parts the release stud in the adapter kit and frees the
setting assembly from the packer for retrieval.
The B-2™ setting tool can be used to set packers in sizes 23 and larger. This
setting tool is designed to withstand high-tensile loads and may be run with hightemperature seals rated at 550°F (288°C). After the packer is run to setting depth,
a tripping ball is dropped and seats in the setting tool. A combination of pressure
and tension may be used to set the packer. Before disengaging the B-2 setting tool
from the packer, the annulus may be pressurized to conirm the packer has been set
successfully. Right-hand rotation disengages the setting tool from the packer.
J Hydraulic
Setting Assembly
Product Family No. H41371
B-2 Hydraulic
Setting Tool
Product Family No. H41574
85
Packer Setting Systems
BH and BHH Setting Tools
Product Family Nos. H41576 and H41577
APPLICATION
Baker Hughes BH™ and BHH™ setting tools are designed to enable the setting of
Baker Hughes D™, DA™, F™ and FA™ type packers on drillpipe. Both can develop a
force of up to 126,000 lb (57 152 kg) and a 10-in. (3.05 m) stroke.
Advantages
„„Drillpipe
connection supplied as standard
is fitted with tubular extension for gripping in tongs, slips
and elevators
„„10-in. stroke ensures setting of slips on a complete range of products
„„Pressure testing can be done before releasing from the packer
„„Tensile load capacity of 150,000 lb (68 038 kg)
„„Pressure rating of 10,000 psi (689.5 bar) in burst and collapse
„„Special shear feature prevents the setting nut (of the BH) and latch (of the
BHH) from being made up too tightly
„„Tool
Additional Information
The BH and BHH setting tools are attached directly to the packer by the setting nut
(of the BH) and latch (of the BHH), which screw into the left-hand thread at the top
of the packer. The tool is actuated by differential tubing or drillpipe pressure. The BH
and BHH can be rotationally released. While the BH setting tool consists of a solid
setting nut, the modiied setting-latch mechanism of the BHH allows for three distinct
methods of release: hydraulic, shear, or rotational release.
BH Setting Tool
Product Family No. H41576
BHH Setting Tool
Product Family No. H41577
86
Packer Retrieving Systems
S-1 Retrieving Tool
Product Family No. H48853
APPLICATION
The S-1™ retrieving tool is used to retrieve SC™ Series, HP™ Series and Model A™
Retrieva-D series packers. It can be used with jars and the top sub has a tool joint
connection for greater strength. Flat surfaces on the anchor mandrel and crossover
sub provide superior jarring surfaces. The mandrel is keyed to the anchor mandrel,
allowing rotation in any position. For strength, all internal threads are acme and the
entire tool is manufactured from heat-treated steel. The S-1 is recommended for
the most rugged conditions and it can be run with drill collars and jars. For proper
retrieving operation, the S-1 retrieving tool must pass through and extend below the
packer. When running accessory equipment on the packer, the ID immediately below
the packer must be able to accept the retrieving tool.
S-1 Retrieving Tool
Product Family No. H48853
87
Packer Retrieving Systems
Premier Workstring Retrieving Tool
Product Family No. H78464
APPLICATION
The Premier™ workstring retrieving tool (POWER tool) is designed for a one-trip removal of a Premier packer
on a workstring. The POWER tool combines the ield- proven components of a S-1 retrieving tool and the DB
underreamer run in on a work string consisting of jars, drill collars, or- if rotation of the pipe is not possiblewith a downhole motor.
Advantages
„„High-tensile
strength throughout the retrieving tool enables removal of the packer and long
lengths of tailpipe below the packer
„„Suitable for use with mud motor; in applications with upper extended-length polished-bore
receptical, the POWER tool can be adjusted with spacer subs and mud motor to allow retrieval of
the entire completion assembly
„„Clutch mechanism allows emergency disengagement of POWER tool with tension and
right-hand rotation
„„Customized design; bearing below top sub allows underreamer to rotate and cut-packer mandrel
SPECIFICATION GUIDE
Casing
OD
in.
5-1/2
Packer
Weight
mm
139.7
lb/ft
20–23
32–35
7
177.8
29–32
26–29
33.7–39
7-5/8
193.6
29.7–33.7
47–53.5
9-5/8
244.5
40–47
Size
450-(36x)239
582-(47x)387
582-(47x)376
582-(36x)287
591-(47x)387
591-(47x)376
591-(36x)287
598-(47x)387
598-(47x)376
598-(36x)287
645-(47x)387
645-(47x)376
659-(47x)387
659-(47x)376
831-(60x)490
831-(60x)475
831-(47x)387
845-(60x)490
845-(60x)475
845-(47x)387
Max OD
in.
4.500
mm
114.3
5.820
147.8
5.910
5.983
6.450
150.1
152.0
4.750
120.7
3.625
92.1
4.750
120.7
3.625
92.1
4.750
120.7
3.625
92.1
4.750
120.7
163.8
6.590
167.4
8.310
221.1
8.450
POWER
Upper
Sealbore
in.
mm
3.625
92.1
214.6
6.000
155.8
4.750
120.7
6.000
155.8
4.750
120.7
Min ID
in.
2.390
3.875
3.760
2.870
3.875
3.760
2.870
3.875
3.760
2.870
3.875
3.760
3.875
3.760
4.900
4.750
3.875
4.900
4.750
3.875
mm
60.7
98.4
95.5
72.9
98.4
95.5
72.9
98.4
95.5
72.9
98.4
95.5
98.4
95.5
124.5
120.7
98.4
124.5
120.7
98.4
Size
450-36x239
582/591/598-47x387/376
582/591/598-36x287
582/591/598-47x387/376
582/591/598-36x287
582/591/598-47x387/376
582/591/598-36x287
645-47x387/376
659-47x387/376
831/845-60x490
831/845-60x475
831/845-47x387
831/845-60x490
831/845-60x475
831/845-47x387
Premier packer must be equipped with upper sealbore for POWER tool to latch into.
POWER Tool Premier
Workstring Retrieving Tool
Product Family No. H78464
88
Seal Assemblies
Downhole Sealing Systems
A variety of downhole sealing accessories are available for connecting tubing with packers. Each is designed to meet speciic requirements of
certain completion techniques. To select the proper packer-to-tubing seal system for any well completion, carefully consider present and future
well conditions. Factors which must be considered include:
„„Seal
movement
pressure differential
„„Maximum and minimum temperatures
„„Well fluids (H S, CO or other corrosives and inhibitors)
2
2
„„Workover frequency
„„Hole geometry
„„Required internal diameter for flow rate and access downhole
„„Tensile forces (packer to tubing)
„„Actuation and release mechanisms
„„Packer design
„„Maximum
As well designs and completion techniques have advanced, so have the number and variation of specialized downhole-sealing systems. The four
main categories of downhole sealing systems are: locators, anchors, on-off tools, polished-bore receptacle and expansion joints. Each category has
variations to handle special circumstances. For information, speciications and order information, contact your local Baker Hughes representative.
Locator Tubing Seal Assembly
The locator tubing-seal assembly is the most basic packer-sealing system for packers incorporating a sealing bore. It is run in the well on the
production tubing string until its no-go shoulder locates on the top of the packer. This positions one or more seal stacks in the packer's sealbore
and establishes a seal between the packer and tubing. When a locator tubing-seal assembly is landed in a packer, the tubing is normally set in
compression to compensate for any contraction of the tubing during treating operations. However, it is not always possible or desirable to slack
off suficient weight, particularly in deep deviated wells. In such cases, additional length must be added to the packer's sealbore using sealbore
extensions and to the locator tubing-seal assembly using a combination of spacer tubes and additional seal units.
K and N Locator Tubing
Seal Nipples
G Locator Tubing
Seal Assembly
APPLICATION
K™ and N™ locator tubing seal nipples are used for
sealing the upper bore of alternate-bore sealbore
packers. One seal stack is used on this seal nipple.
No upward movement can be tolerated, therefore
suficient set-down weight must be available to
prevent movement.
Product Family No. H44234
K-22 Locator
Tubing Seal Nipple
Product Family No. H44251
APPLICATION
The G™ basic assembly includes two seal stacks. Any
number of seal units or spacer tubes can be added for
increased length. It is designed for use in single-bore
sealbore packers. They are also compatible with
the lower sealbore in most sizes of alternate-bore
sealbore packers. Production tubes, tailpipe or other
accessories with ODs compatible with packer bore
can be attached to the bottom of this seal assembly.
G-22 Locator Tubing
Seal Assembly
Product Family No. H44234
89
Seal Assemblies
G Locator Tubing Seal
Assembly With Spacer Tube
Product Family No. H44280
APPLICATION
The G™ locator tubing seal assembly is designed for installations requiring
tubing movement, this seal assembly should only be used with packers that have
sealbore extensions or with retrievable packer-bore receptacles. Like all locator
tubing seal assemblies, it should be landed with suficient set-down weight to
prevent seal movement. When used in a properly designed system, this seal
assembly will give long service life even if movement occurs.
L, LE and LM Locator Tubing
Seal Assemblies With Spacer Tube
APPLICATION
L™, LE™ and LM™ seal assemblies are similar to the G locator tubing seal
assembly with spacer tube but are designed for use in the extremely hostile
environments of D™, F-1™, HE™, SB-3™, and SC-2™ sealbore packers. They are
normally furnished with three seal stacks and three debris barriers. The L features
metal-to-metal internal connections and is used with premium seal stacks. The
LM also features a compression energized metal-to-metal packer-to-tubing seal.
G-22 Locator Tubing Seal
Assembly with Seal Units
Product Family No. H44280
90
L-22 Locator Tubing Seal
Assembly with Seal Units
Product Family No. H44601
Seal Assemblies
Anchor Tubing Seal Assembly
The anchor tubing seal assembly is used as an alternative to set-down weight; it prevents seal movement or is used when it is preferable to land
the tubing in tension. The anchor tubing seal assembly or anchor tubing seal nipple is run in on the production string. Set-down weight causes the
anchor's threaded latch to engage the corresponding threads in the top of the packer. Once engaged, the anchor and tubing are securely locked in
place. Any tubing contraction will cause a tensile load to be applied to the tubing string. Care must be taken to ensure tensile forces that develop
will not part the tubing whenever an anchor is used. To release the anchor, it must be rotated to the right 10 to 12 turns at the packer.
Many variations to the anchor tubing seal assembly exist to fulill special requirements, such as: snap-latch, latch-in shear release, snap-in/snapout set-down activated-shear release, annular pressure release (not shown) and tubing pressure release (not shown), solid-nut (not shown) and
punch release. for further information about anchor tubing assemblies in special applications, contact your Baker Hughes representative.
E and EC Anchor TubingSeal Assemblies
M Anchor TubingSeal Assembly
APPLICATION
E™ and EC™ basic assemblies includes two seal
stacks and is designed for use in sealbore packers.
Production tubes, tailpipe or other accessories that
have ODs compatible with the packer bore can be
attached to the bottom of this seal assembly. The
EC features metal-to-metal internal connections
for hostile environments.
Product Family No. H44701
E-22 Anchor Tubing
Seal Assembly
Product Family No. H44344
K, KC, KC-1 and KC-2
AnchorTubing-Seal Nipples
Seal Assemblies
APPLICATION
K™, KC™, KC-1™ and KC-2™ tubing seal nipples are
used for sealing in the upper bore of alternate-bore
sealbore packers. It is supplied with one seal stack
and blank or half-mule shoe bottom sub, which will
not accommodate tailpipe or production tubes.
The KC, KC-1 and KC-2 anchors feature metal-tometal internal connections for hostile environments.
The KC-2 anchor tubing seal assembly is to be used
exclusively with the SABL-4™ packer in the North
Sea-standard completion
K-22 Anchor Tubing
Seal Assembly
Product Family No. H44338
APPLICATION
Similar to the E anchor tubing seal assembly, the
standard assembly includes two seal stacks. The M™
features metal-to-metal internal connections and is
used with premium seal stacks.
M-22 Anchor Tubing
Seal Assembly
Product Family No. H44701
N and NM Anchor Tubing
Seal Assemblies
APPLICATION
N™ and NM™ tubing assemblies are similar to the
K anchor tubing seal nipple, but are designed for use
in extremely hostile environments in the alternate
bore of sealbore packers. The NM features metal-tometal internal connections and premium seal stacks.
The NM also features a compression-energized
metal-to metal, packer-to-tubing seal.
N-22 Anchor Tubing
Seal Assembly
Product Family No. H44351
91
Seal Assemblies
E ™ Snap-Latch
Seal Assembly
Product Family No. H44403
Snap-latch seal assemblies are similar to
shear-release anchor seal assemblies because
they are latched in place with set-down weight
and released with tension. However, unlike shearrelease anchors, snap-latch seal assemblies may
be snapped into and out of, a packer many times.
Initially, 8,000–12,000 lb (3 628–5 443 kg) of tension
is required to remove the snap-latch from the packer’s
bore. Snap-latch seal assemblies are used
in installations that require a mechanical snap-in,
snap-out to verify the seal assembly is properly
positioned in the packer’s bore. Typical applications
include sump packers in gravel packs and lower
packers in tandem completions that cannot be
pressure-tested.
E Snap-Latch
Seal Assembly
Product Family No. H44403
E, K™ and N™ Latch-In Shear
Release AnchorTubing
Seal Assemblies
A latch-in shear-release anchor tubing seal assembly
may be used for those installations when anchored
seal assemblies are preferable, but the tubing cannot
be rotated to release the anchor. Set-down weight
is used to latch the shear-release anchor into the
packer and tension is used to release it. The shear
value of the latch-in shear-release anchor tubing seal
assembly may be speciied to suit the application.
E Latch-In Shear Release
Anchor Tubing Seal Assembly
Product Family No. H44370
Hydraulic Punch Releasable Anchor
Product Family No. H44757
APPLICATION
The Baker Hughes hydraulic punch releasable anchor is a unique anchor and packer-bore receptical (PBR) assembly
designed speciically for applications where rotation for release is not available, such as deepwater wells.
Advantages
„„Single-trip
completion
removal of tubing string without rotation or chemical cut–adding workover flexibility to deep
wells or applications with high-alloy tubing
„„Metal-to-metal nose seal available
„„Proven Baker Hughes punch communication tool technology for activating release mechanism
„„PBR is retrievable with the packer by drillpipe workstring and retrieving tool
„„Packer-anchor assembly can be internally pressure-tested in the field
„„Applying low tubing pressure actuates releasing mechanism, tensile load shear-releases the anchor
assembly from the PBR
„„Control line-cutter mechanism available for feedthrough applications
„„Permits
Additional Information
Release of the anchor is performed with a punch tool originally developed for use in safety valves, which opens a
shifting port. Pressurizing the tubing positively releases the anchor for retrieval.
92
Hydraulic Punch
Releasable Anchor
Product Family No. H44757
Seal Assemblies
Snap-In/Snap-Out, Set-Down-Activated, Shear-Release Anchor
Product Family No. H44387
APPLICATION
The snap-in/snap-out, set-down-activated, shear-release anchor is an anchoring and sealing device that connects
the retrievable tubing string to the upper sealbore and thread of an alternate-bore permanent packer. Alternatively
the anchor can be connected to a retrievable packer that incorporates the proile of a permanent packer.
Advantages
„„Snap-in/snap-out
facility at the packer allows operator to accurately land tubing string at surface
predetermined set-down load activates anchor to full-tensile carrying capacity
„„Set-down sleeve protects upper sealbore of packer from debris intrusion
„„Emergency release facility, by means of right-hand torque and an overpull at surface, will disconnect
anchor from packer
„„Left-hand square threads on latch are coated with Bakertron™, reduces galling of mating threads in highchromium applications
„„A
Additional Information
Snap-In/Snap-Out, Set Down
Activated, Shear Release Anchor
Product Family No. H44387
Before committing to full engagement of the anchor, the snap-in/snap-out facility allows accurate positioning or
space-out of the tubing string at surface in relation to a tubing hanger. As long as the predetermined set-down
weight is not exceeded, the tool will continue to have the ability to snap-in and snap-out of the packer body without
committing to its fully locked-in tensile-carrying condition.
CAUTION: The snap-in/snap-out set-down-activated shear-release anchor requires an extended upper sealbore from
the standard packer bore. Contact your local Baker Hughes representative to conirm anchor/packer compatibility.
Ratcheting Muleshoe
Product Family No. H44457
APPLICATION
The new ratcheting muleshoe offers a simple and reliable alternative for landing-seal assemblies in sealbore
packers when tubing rotation is either impossible or objectionable. The ratcheting mule shoe indexes
automatically one-eighth turn each time the top of the packer is tagged or until the half-mule shoe bottom
positions itself properly to enter the packer bore. The mule shoe features a short, compact design and rugged
construction. It is indispensable for spacing out and landing seals in the lower sealbore packer of a dualstring hookup when tubing rotation is impractical. It is especially suitable when tubing-mounted safety valves
are being run to avoid damage to the control lines.
Ratcheting Muleshoe
Product Family No. H44457
93
Seal Assemblies
Seal Stacks
Standard Seal Stacks–made up of nitrile chevron seals and steel spacer rings.
Should remain in sealbore during service.
Bonded Seal Stack–Two nitrile or Viton seals are bonded to each metal insert.
These inserts are separated by steel spacers. Bonded seals should be used when
seals cannot be prevented from moving out of the sealbore while holding differential
pressure. Also recommended for sealing low-pressure gas at low temperatures.
V-RYTE Seal Stack–Made up of Viton chevron seals with Telon and Ryton*
backup rings, Ryton front-up rings and steel separators. Should remain in sealbore
during service.
Spacer
Chevron Seal
Standard
Seal Stack
Bonded Seal Ring
A-RYTE Seal Stack–Made up of Alas chevron seals with Telon and Ryton backup
rings, Ryton front-up rings and steel separators. Should remain in sealbore
during service.
A-HEET Seal Stack–Made up of Alas chevron seals with Telon and HEET backup
rings, HEET front-up rings and steel separators. Should remain in sealbore
during service.
O-Ring
Spacer
Bonded
Seal Stack
RYTE Seal Stack–Made up of PS006 chevron seals with Telon and Ryton backup
rings, Ryton front-up rings and steel separators. Should remain in sealbore
during service.
Back-Up Ring
Seal-RYTE Seal Stack–Made up of Perluoroelastomer chevron seals with Telon
and Ryton backup rings, Ryton front-up rings and steel separators. Should remain in
sealbore during service.
Back-Up Ring
Chevron Seal
Front-Up Ring
K-RYTE and K-HEET Seal Stacks–Made up of KALREZ brand Perluoroelastomer
chevron seals with Telon and Ryton or HEET backup rings, Ryton or HEET front-up
rings and steel separators. Should remain in sealbore during service.
Debris Barrier Stack–Made up of Telon and Ryton backup rings and Ryton frontup rings and steel separators. Used as a wiper to prevent debris from damaging
KRYTE, K-HEET, A-HEET or Seal-RYTE seal stacks when seals are moved after being
placed in service.
Spacer
_ - RYTE
_ - HEET
Spacer
Wiper Ring
Wiper Ring
Debris
Barrier Stack
* Ryton is a registered trademark of ChevronPhillips chemical company.
94
Seal Assemblies
PACKER-TO-TUBING PACKING UNIT SELECTION GUIDE
Seal Type
Pressure Differential
Non-Unloading
Unloading
PSI
Nitrile
Chevron
10,000
70 Hard
Nitrile
Bonded
5,000
90 Hard Nitrile
Bonded
10,000
95 Hard Viton
Bonded
10,000
MPa
68.9
34.4
68.9
68.9
PSI
NO
5,000
5,000
5,000
MPa
NO
34.4
34.4
34.4
Environmental Compatibility X
Temp. Range
°F
32–300
32–200
32–300
32–250
°C
0–149
0–93
0–149
0–121
H2S
NO
NO
NO
5%
Oil Base
Completion
OK
OK
OK
OK
Light Brine
Completion
CaBr2/NaBr2
OK to 250°F
High pH
Completion
pH > 10
NO
pH >10
ZnBr2
NO
CaBr2/NaBr2
OK to 250°F
OK to 250°F
pH <10
NO
pH >10
ZnBr2
NO
CaBr2/NaBr2
OK to 250°F
OK to 250°F
pH <10
NO
pH >10
ZnBr2
NO
OK to 250°F
pH <10
OK
NO
OK
to 200°F
OK
OK
Bromide
Completion
OK
OK
OK
OK
Amine
Inhibitors
OK
to 200°F
OK
to 200°F
OK
to 200°F
CaBr2/NaBr2
OK to 250°F
HN-Ryte™
10,000
68.9
NO
NO
32–350
0–177
2%
OK
OK
ZnBr2
NO
X
l
n
V-Ryte™
15,000
103.3
NO
NO
A-Ryte™
15,000
103.3
NO
NO
A-HEET™
15,000
103.3
NO
NO
K-Ryte™
K-HEET™
Seal-Ryte™
Seal-HEET™
R-Ryte™
Molyglass
15,000
15,000
15,000
15,000
10,000
10,000
103.3
103.3
103.3
103.3
68.9
68.9
NO
NO
NO
NO
NO
NO
NO
NO
NO
NO
NO
NO
32–300
32–400
80–300
80–450
80–300
80–450
100–450
100–550
40–450
40–450
325–450 l
125–300
0–149
0–204
27–149
27–232
27–149
27–232
38–232
38–288
4–232
4–232
163–232
52–149
15%
5%
20%
7%
20%
15%
7%
n
7%
n
7%
15%
OK
OK
OK
NO
OK
to 200°F
NO
OK
OK
OK
OK
NO
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
Explosive decompression is both chemical and mechanical in nature related to the solubility of gas in elastomer and strength of the elastomer. The elastomeric seals
in these units may be susceptible to explosive decompression, however, explosive decompression does not usually occur while seals are in service.
Refer to Baker Hughes' packer systems technical manual, Unit No. 8218-3, for complete temperature range information.
There are no known H2S limitations below 500°F (200°C).
95
Seal Assemblies
Retrievable Packer Bore Receptacle
Optional shear screw release allows
shear valves to be field adjustable.
Product Family No. H68319
APPLICATION
Baker Hughes retrievable packer bore receptical (PBR) systems are
installed in wells as part of a completion to accommodate expansion and
contraction of production tubing, while maintaining pressure integrity.
The retrievable PBR is run as an integral part of the production tubing
above the completion packer. The most common completion method
is to run the PBR as pictured with the seal assembly fully inserted into
the receptacle. After reaching the desired depth, suficient tension is
applied to shear the screws or shear ring. The well can then be spaced
out as desired.
Standard Z-shape shear ring retains
spent shear ring parts to reduce
potential problems.
Debris
Barrier
Advantages
„„Accommodates
expansion and contraction of tubing
„„Seals can be removed and replaced without unsetting packer
„„Largest possible ID through completion
„„Seals fully protected during run in
„„Seal unit configuration reduces risk of hydrostatic lock
„„Available in custom lengths
Debris
Barrier
Holds
differential
pressure
from below
Additional Information
When combined with the hydraulic-set packer such as the Premier™,
SB-3™ and SAB-3™, the completion can be run in and set on the
production tubing string in one trip. If desired, the well can be
langed up and the tubing string displaced before setting the packer.
A retrieving tool (H68396) is used to retrieve the PBR.
SPECIFICATION GUIDE
Tubing Size
in.
mm
2-3/8
60.3
2-7/8
73.0
3-1/2
88.9
4-1/2
114.3
Tool Size
40–26
Holds
differential
pressure
from above
Directionally oriented seal units
are designed to hold pressure
from one direction only. They
are preserved in PBR
applications to reduce the
chance of trapping an area
of atmospheric pressure
between the functional
seal stacks.
Contact your local Baker Hughes
representative for function
discussion on seal orientation.
Debris
Barrier
Non-sealing debris barriers serve two
important functions: they keep well solids
or trash from setting in the annular
area between the honed bore and
seal assembly which may impede the
movement of the seal assembly. They also
clean the sealing area before functional
working seals contact the sealbore.
20–30
20–32
80–32
80–40
80–47
80–48
Retrievable PBR with seal assembly
(may be pre-spaced for upward and
downward movement)
Product Family No. H68319.
190–60
5-1/2
139.7
6-5/8
168.2
190–71
7
177.8
190–73
192–60
Retrievable PBR Retrieving Tool
Product Family No. H68396
96
Seal Expansion/
Disconnect Devices
Tubing Stability Latch (TSL)
Product Family No. H68347
APPLICATION
The TSL consists of a special latch designed to be used with a packer bore
receptical (PBR). The primary function of the TSL is to keep the seals static
in the PBR during all well conditions, except extreme treating/stimulation
operations. During such conditions, the TSL automatically releases the latch
and allows the seals to loat. The latch automatically re-engages after the
extreme tubing load event, retaining the seals in the static condition. The TSL
is a valuable aid to life of well seal integrity.
Advantages
„„PBR
seals are static during long-term well operations until triggered
by extreme treating/stimulation operations
„„Increases seal life and reliability
„„Reduces tubing-string costs when compared to an anchor-based
|completion design
„„Reduces high compressive load requirements when compared to a
traditional floating seal design
„„Reduces tubing stress
„„Metal-to-metal seals on all threaded connections
Tubing Stability Latch (TSL)
Product Family No. H68347
97
Seal Expansion/
Disconnect Devices
Models A and A-1 Extenda-Joint
Product Family Nos. H68357 and H68354
APPLICATION
The Model A™ Extenda-Joint™ is a high-performance tubing-expansion joint used
when tubing movement is expected because of temperature and pressure changes
during treatment and anchor seal assembly. To provide very accurate release forces,
the slick joint and the outer housing are locked together during run-in by a shear ring
instead of shear screws.
Advantages
„„Metal-to-metal
connections in housing and slick joint eliminates
O-ring seals
„„Optional seating nipple profile in upper end of slick joint
„„Up-shear ring secures slick joint to housing for running in
„„Standard stroke lengths 10 ft (3.05 m), 15 ft (4.57 m), 20 ft (6.10 m)
and 25 ft (7.62 m)
„„Built-in capability for testing to full working pressure in assembled
condition
„„One-piece seal housing accommodates both sets of working seals for extra
strength and ease of redressing and reduces chances of frozen seals
„„V-Ryte™, A-Ryte™, K-Ryte™ or standard nitrile-chevron seals are available
„„Debris barriers located above and below working seal protects seals
„„Suitable for H S service per NACE Standard MR-01-75
2
Additional Information
The A-1 Extenda-Joint tool offers the same features and beneits as the Model A
Extenda-Joint at a lower cost and with fewer connections and resulting leak paths.
Model A Extenda-Joint
Product Family
No. H68357
98
Seal Expansion/
Disconnect Devices
SPECIFICATION GUIDE
Model A™ Extenda-Joint, Product Family No. H68357
Slick Joint
Tubing Size
Max OD
Tool Size l
ID n
OD
Max BFC
Profile ▲
in.
mm
in.
mm
in.
mm
in.
mm
2-3/8
60.3
26–(3.80x–)
3.803
96.6
2.688
68.3
1.939
49.3
2-7/8
73.0
33–(5.13x–)
5.126
130.2
3.315
84.2
2.371
60.2
36–(4.80x–)
3-1/2
4.803
1.87
2.31
2.81 F & R
122.0
88.9
92.1
3.625
36–(5.40x–)
5.400
137.12
43–(5.90x–)
5.900
149.9
2.75 Sur-set
75.7
2.902
2.81 F & R
2.75 Sur-set
4
101.6
45–(5.90x–)
4-1/2
5.900
149.9
7.026
l
n
▲
139.7
88.3
3.476
3.31
3.81 F & R
101.6
4.000
3.43 Sur-set
178.5
49–(7.03x–)
X
115.6
4.550
114.3
48–(7.03x–)
5-1/2
108.6
4.275
55–(7.66x–)
7.656
194.5
4.875
123.8
4.925
125.1
5.500
139.7
3.958
100.5
3.81
4.788
121.6
4.56
Special clearance version.
The basic tool size is indicated by four digits. When ordering, show stroke length of the slick joint in place of the blank spaces. Example: 33–(5.13x–)
with 20 ft (6.1 m) stroke will read: 3320 (5.13x–). The blank space in the parenthesis is used to designate the bore of the BFC profile. Use the first two digits of the profile.
Example: 3320 (5.12x23) has a 2.31 bore. Specify the profile type required i.e., F, R, AF, AR, etc.
Maximum slick joint ID without seating nipple profile.
Maximum BFC seating nipple profile size, consistent with rated pressure for tool. Smaller BFC profiles may be furnished upon request.
Contact your local Baker Hughes representative for additional information concerning test pressures.
A-1™ Extenda-Joint, Product Family No. H65354
Slick Joint
Tubing Size
Max OD
Tool Size
in.
4-1/2
5-1/2
X
l
mm
114.3
139.7
OD
in.
45
54 and 55 l
5.900
8.25
mm
149.9
209.6
in.
4.550
5.500
Max BFC
Profile
ID
mm
115.6
139.7
in.
mm
3.395
86.2
3.476
88.3
4.670
118.9
3.43
4.56
ID with nipple profile (this may also reduce pressure rating)
A-1 Extenda-Joint available in size 54 only.
99
Disconnect Devices
L-10, R-10, L-316 and R-316 On-Off
Sealing Connector Family
Product Family Nos. H68420, H68421 and H68437
APPLICATION
The on-off sealing connector has the capability to simply and reliably retrieve
the production string without disturbing the companion packer below. Its sealing
system allows the tubing to be disconnected for luid circulation, while ensuring
seal integrity when reconnected.
Advantages
„„Short,
compact design
sealing system
„„Available with bonded or non-elastomeric seals
„„Orientation of seals eliminates need for O-rings
„„Fit for environment
„„Metallurgies–standard service or NACE service
„„Elastomers–nitrile or thermoplastic non-elastomeric
„„Rated to 10,000 psi (689.5 bar) @ 275°F (135°C) with bonded seals
and 12,000 psi (827.4 bar) @ 350°F (135°C) with nonelastomeric seals
„„Fully tested in gas at maximum temperature with multiple
pressure reversals
„„Tensile rating compatible with L-80 tubing in NACE trim
„„Tensile rating compatible with P-105 tubing in standard material
„„Only top sub and seal nipple are exposed to flow
„„No welded parts
„„Can be set to shear up or down
„„Automatic re-engagement with set-down weight
„„Superior
Additional Information
A seating nipple proile is available in the top of the seal nipple to permit
plugging of the lower zone, while the tubing is removed. Besides the left-hand
releasing L-10 version, a right-hand releasing R-10 version is also available,
enabling remedial or stimulation work above the packer. The plug can then be
removed with conventional wireline methods, allowing production of the well
to resume. The L-316 has all the design features built into the L-10, but it is
designed speciically for CO2 and waterlood applications. It uses 316 Stainless
Steel low path material while maximizing load capacity. The tubing pressure
rating of 4,500 psi (310.2 bar)is available with bonded (40°F–275°F) (4°C–135°C)
or non-elastomeric (40°F–325°F) (4°C–163°C) seals.
L-10 On-Off Sealing
Connector Family
Product Family No. H68420
100
Disconnect Devices
SPECIFICATION GUIDE
L-10™, R-10™, L-316™, R-316™, LE-10™, RE-10™ and BE-10™ On-Off Sealing Connectors
Recommended Casing Ranges
Tool Size
Min Seal Nipple ID
Washover Shoe OD (Max)
OD
in.
mm
in. (mm)
in.
3.750
mm
95.3
Weight
in.
mm
lb/ft
4-1/2
114.3
9.5–13.5
5
127.0
11.5–24.1
5-1/2
139.7
6-5/8
168.3
20–23
13–23
4.500
2-3/8
60.3
1.87 (47.5) w/ Profile
1.930 (49.0) w/ Blank ID
5.500
6.250
73.0
88.9
158.8
206.4
4.500
114.3
139.7
2.31 (58.7) w/ Profile
2.377 (60.4) w/ Blank ID
6.250
3-1/2
139.7
8.125
5.500
2-7/8
114.3
2.81 (71.4) w/ Profile
2.942 (74.7) w/ Blank ID
158.8
8.125
206.4
5.500
139.7
5.888
149.6
7.250
184.2
8.125
206.4
20–32
7
177.8
23–38
6-5/8
168.3
20–32
7
177.8
17–38
7-5/8
193.7
24–47.1
8-5/8
219.1
24–49
7
177.8
17–20
7-5/8
193.7
24–45.3
8-5/8
219.1
24–49
9-5/8
244.5
32.3–53.5
5-1/2
139.7
13–23
6-5/8
168.3
20–32
7
177.8
17–38
7-5/8
193.7
24–47.1
8-5/8
219.1
44–49
7
177.8
17–20
7-5/8
193.7
24–45.3
8-5/8
219.1
24–49
9-5/8
244.5
32.3–53.5
6-5/8
168.3
20–32
7
177.8
17–38
7-5/8
193.7
24–47.1
6-5/8
168.3
20
7
177.8
17–32
7-5/8
193.7
24–47.1
8-5/8
219.1
32–49
24–49
9-5/8
244.5
32.3–53.5
101
Expansion Joints
EXPANSION JOINT SELECTION GUIDE
L
M
Slimline Design
x
x
Pre-spaced with Model A Spacing Tool
x
N
Pre-spaced with Shear Screws
LEEJ
Splined
E
LEEJ
x
x
x
10
10
x
Full Opening ID
x
x
Swivel Capability/Clutched in Expanded Position
x
x
Standard Stroke
16
20
x
x
x
10
Rotational Lock
9
x
x
N Splined
Expansion Joint
E Tubing
Expansion Joint
Product Family No. H44163
Product Family No. H44145
APPLICATION
The Baker Hughes N™ splined expansion joint is
designed for use in both single- and multiple-string
completions to compensate for tubing movement. The
tool provides 10 ft (3.045 m) of movement and uses
rugged bonded seals for reliable continuous service.
The telescoping action permits the tool to be used as a
bumper sub or jar when retrieving the installation.
APPLICATION
The Baker Hughes E™ expansion joint is designed
for use above packers in well completions, to
compensate for tubing movement during treating
and injections operations. The E joint contains
standard chevron seals or bonded seals.
Advantages
„„Rotational
lock in extended position
transmits torque when needed
„„Extra-long seal area provides adequate
sealing in case of side load
„„Temperature rating up to 325°F (163°C)
Advantages
„„Shear
screws easily added or removed to
adjust shear value
„„Tool locks in fully extended, fully collapsed
or mid-stroke position with shear screws
„„Full-length keys provide transmission of
torque through full length of travel
„„Metal goods suitable for H S service per
2
NACE Standard MR-01-75
N Splined
Expansion Joint
Product Family
No. H44163
Additional Information
The E joint is also a swivel joint, unless extended
E Tubing
to its full stroke when a clutch engages and allows
Expansion Joint
Product Family torque to be transmitted through the joint. It
No. H44145
commonly provides 9 ft (2.74 m) of movement.
Additional Information
Shear screws may be installed to initially position the
expansion joint in its extended, collapsed, or
mid-position.
A rotation lock lets the operator rotate through the
expansion joint in any position.
N Splined Expansion Joint
in.
2-3/8
2-7/8
3-1/2
4-1/2
102
Max
OD
in.
3.688
4.531
4.906
6.531
mm
93.6
115.0
124.6
165.8
Min
OD
in.
1.930
2.441
2.875
3.875
mm
49.0
62.0
73.0
98.4
Extended
Length
in.
273
283
276
278
mm
693.4
718.8
701.0
706.1
Fully
Collapsed
Length
in.
mm
157 396.7
162 411.4
156 396.2
158 401.3
Torque
Rating
ft-lb
2,000
2,500
3,500
5,000
E Tubing Expansion Joint
Tubing
Size
in.
2-3/8
2-7/8
3-1/2
4-1/2
SPECIFICATION GUIDE
Tubing
Size
SPECIFICATION GUIDE
kg-m
277
346
484
691
Max OD
in.
3.750
4.500
5.000
5.500
mm
92.5
114.3
127.0
139.7
Min OD
in.
1.968
3.690
3.880
4.880
mm
50.0
93.7
98.6
124.0
Stroke
Length
ft
9
9
9
12
m
2.74
2.74
2.74
3.66
Fully
Collapsed
Length
in.
mm
167.5 4.255
167.5 4.255
150.7 3.828
208.0 5.283
Expansion Joints
L Expansion Joint
Product Family No. H44160
Model A Positioning Tool
Product Family No. H44165
M Expansion Joint
Product Family No. H44162
APPLICATION
The L™ and M™ expansion joints are slim-line tools primarily designed for use
in dual-string completions. The L expansion joint can be pre-spaced, using the
Model A™ positioning tool, to allow upward and downward movement. The L is
ideal for one-trip langed up dual completions when extreme tubing movement
is anticipated. Once the packer has been set, the Model A positioning tool is
retrieved on wireline permitting movement. The M expansion joint does not
permit pre-spacing.
Advantages
„„Full-opening
ID compatible with tubing ID
of tool compatible with dual-string applications
„„Standard stroke lengths up to 20 ft (6.1 m) (M expansion joint) and 16 ft
(4.9 m) (L expansion joint); other lengths available upon request
„„Functions as a swivel until stroked out; available with optional
rotational clutch
„„V-Ryte seals are standard, other sealing materials are available
upon request
„„Suitable for H S Service per NACE Standard MR-01-75
2
„„OD
SPECIFICATION GUIDE
Max Tool OD
Min Tool ID
Tubing Size
Model L
X
Model M
Model L 
Model M
in.
mm
in.
mm
in.
mm
in.
mm
in.
mm
2-3/8
60.3
3.505
89.0
3.250
82.5
1.937
49.2
1.939
49.2
2-7/8
73.0
4.005
101.7
3.765
95.6
2.374
60.3
2.374
60.3
3-1/2
88.9
4.260
108.2
4.260
108.2
2.840
72.1
2.890
73.4
4-1/2
114.3
-
-
5.390
136.9
-
-
3.895
98.9
5-1/2
139.7
-
-
7.070
179.5
-
-
4.830
122.6
ID required to accommodate Model A positioning tool, Product Family No. H44165
L Expansion Joint With
Model A Positioning Joint
Product Family No. H44160
M Expansion Joint
Product Family No. H44162
103
Spacing Devices
LEEJ Expansion Joint Non-Splined and Splined
Product Family Nos. H44167 (Non-Splined) and H44168 (Splined)
APPLICATION
The non-splined and splined versions of the LEEJ™ expansion joint, Product Family Nos. H44167 and H44168,
are designed for use above packers in well completions to compensate for tubing movement during treating
and/or injecting operations.
Advantages
„„Rotational
lock in any position transmits torque when required (splined version only)
can be pinned at 1-ft intervals from closed to fully stroked position (splined version only)
„„Shear value adjustable by varying number of shear screws (splined version only)
„„Premium V-Ryte™ seal stack is standard
„„10-ft stroke standard (both nonsplined and splined versions)
„„Both versions can be supplied with non-standard stroke lengths as an additional option
„„ID compatible with tubing ID
„„Standard VAM pin connection down (with crossover to required customer thread, if different,
as an additional option)
„„Box connection up to customer’s specification
„„Standard-base material AISI 4130 carbon steel (both non-splined and splined versions);
both versions can be supplied in other materials as an additional option
„„Tool
Additional Information
When rotation through the tool is required, the design of the splined version of the LEEJ allows torque to be
applied through the tool in any position; it does not have to be fully extended or fully collapsed for rotation
through the tool. The non-splined version does not permit the transmittal of torque through the tool.
SPECIFICATION GUIDE
Size
OD
ID
Overall Length
Stroke Length
in.
mm
in.
mm
in.
mm
in.
mm
ft
m
2-3/8
60.3
3.250
82.6
1.929
49.0
148
3.759
10
3.05
2-7/8
73.0
3.765
95.6
2.374
60.3
148
3.759
10
3.05
3-1/2
88.9
4.300
109.0
2.915
74.0
158
4.013
10
3.05
LEEJ Expansion Joint
Product Family
Nos. H44167 and H44168
104
Spacing Devices
Adjustable Spacer Sub With Rotational Lock
Product Family No. H44125
APPLICATION
The adjustable spacer sub with rotational lock is used below a dual packer to facilitate
making tubing connections and spacing out between two retrievable packers. The spacer
sub has 24 in. (609.6 mm) of travel and when adjusted to the desired length, it is locked to
prevent telescoping or rotational movement.
SPECIFICATION GUIDE
Max OD
Nom ID
Size
in.
mm
in.
mm
1.900
2.531
64.29
1.563
39.70
2-1/16
2.531
64.29
1.656
42.06
2-3/8
3.094
78.59
1.969
50.01
2-7/8
3.719
94.46
2.375
60.33
3-1/2
4.281
108.74
3.000
76.20
Adjustable Spacer Sub
With Rotational Lock
Product Family No. H44125
Telescoping Swivel Sub
Product Family No. H44120
APPLICATION
The telescoping swivel sub was developed for use in multiple-string completions as
a union to facilitate running additional tailpipe below a dual-string retrievable packer.
The telescoping action of the sub provides 24 in. (609.6 mm) of travel to compensate
for inaccuracies in measurement and to relieve the strain on threads while making up
tailpipe between two dual packers. The swivel feature makes it possible to connect
both long- and short-string tailpipe to the lower end of the packer. Even if the tailpipes
are strapped together, it bears the weight of the tubing hanging in the slips, while the
connection between tubing and packer is being made up.
SPECIFICATION GUIDE
Max OD
Nom ID
Size
1.315
Telescoping Swivel Sub
Product Family No. H44120
in.
mm
in.
mm
1.906
48.41
1.000
25.40
1.660
2.250
57.15
1.313
33.35
1.900
2.531
64.29
1.563
39.70
2-3/8
3.094
78.59
1.969
50.01
2-7/8
3.719
94.46
2.375
60.33
3-1/2
4.281
108.74
3.000
76.20
4-1/2
5.281
134.14
3.938
100.03
105
Spacing Devices
Telescoping Space-Out Joint (TSOJ)
Product Family No. H68376
APPLICATION
The TSOJ is a high-performance device used for spacing out an upper completion into a liner top or lower
completion in a deepwater or subsea well. The TSOJ allows the lower completion to be tagged multiple
times with the tailpipe of the upper completion, before the tubing is landed in the tubing hanger.
Advantages
„„Entire
upper completion hook-up run in one trip
pulling up to space out in subsea/deepwater
„„Avoids dummy runs
„„No expensive PBR required
„„Single- or multiple-shear activation available (3X standard)
„„Simplifies space-out procedures
„„Telescoping action
„„Seals in extended position (optional)
„„No seal when collapsed
„„Rotationally locks in extended position (optional)
„„Based on highly reliable patented TSL multiple shear TSOJ
„„Avoids
Additional Information
The TSOJ provides a positive indication of the downhole position that has been achieved before landing
the subsea tubing hanger. Suficient slack-off (compressive) load activates the tool and allows the tailpipe
to stroke, thereby reducing the length of the bottomhole assembly. In subsea and deepwater applications,
this allows the tubing hanger to be landed without adjusting the length of the production tubing. In an ESP
application this allows the bottomhole assembly to tag and space-out against a sump packer. There is no
compression left in the tailpipe after the tubing hanger is landed. And, the mechanism may be reactivated a
total of three times.
Telescoping
Space-Out Joint (TSOJ)
Product Family No. H68376
106
Multi-String Sealing
Accessories
S Snap-Latch Seal Nipple
Product Family No. H70703
APPLICATION
The S™ snap-latch seal nipple is used to connect the short strings into multiple-string
retrievable packers. The snap-latch provides a positive surface indication when the
nipple snaps into the sealing bore.
Options
„„SA™
and SD™ (Product Family Nos. H70704 and H70709) are variations that add
increased length or diameter
„„SAM™ (Product Family No. H70705) is a muleshoed version of the SA
seal nipple
„„SW™ (Product Family No. H70760) provides a locking sleeve that can be shifted
downward, preventing it from being pumped out of the sealbore
K Parallel Anchor Seal Nipple
Product Family No. H70311
APPLICATION
The K™ parallel anchor seal nipple is used with the A-5™, AL-5™ or GT™ dual-string
packer in conjunction with the parallel head (Product Family No. H70032) to anchor
short-string seals in the packer, thereby eliminating possible pump out.
S Snap-Latch Seal Nipple
Product Family No. H70703
K Parallel Anchor Seal Nipple
Product Family No. H70311
SHORT STRING SEAL NIPPLE AVAILABILITY GUIDE FOR USE WITH DUAL PACKERS
Seal Nipple
Model
Product
Family
No.
Size
1.25
S
H70703
SA
H70704
SAM
H70705
SD
H70709
x
K
H70311
x
SW
H70760
1.43
1.53
1.68
x
x
1.96
2.06
2.18
2.28
2.39
2.50
2.68
3.00
3.25
3.75
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
107
Safety Joints
SAFETY JOINT SELECTION GUIDE
Rotational
Release
Safety Joint
Shear
Release
Short
Stroke
Long
Stroke
Rotationally
Locked
x
Shear-Out Safety Joint
x
B Shear-Out Safety Joint
x
C Shear-Out Safety Joint
x
x
x
x
x
Safety Joint
Product Family No. H44101
APPLICATION
The safety joint provides an emergency disconnect for a portion of the tubing string, should it become
necessary to abandon the equipment below. Precision left-hand square threads facilitate release of the
joint by right-hand tubing rotation.
SPECIFICATION GUIDE
Max OD
Nom ID
Size
in.
mm
in.
mm
1.900
2.22
2-3/8
3.094
56.3
1.53
38.8
78.5
2.000
2-7/8
50.8
3.719
94.4
2.422
3-1/2
61.5
4.531
115.0
2.984
75.7
Shear-Out Safety Joint
Safety Joint
Product Family No. H44101
Product Family No. H44130
APPLICATION
The shear-out safety joint is used between packers in dual completions and in
selective completions using hydraulic/hydrostatic single-string packers. When run
above the upper packer in a single-string completion, however, the shear value should
be adjusted to compensate for any hydraulic conditions that exist when the string is
landed or that are created by well treating operations.
SPECIFICATION GUIDE
Max OD
Nom ID
Size
Shear-Out Safety Joint
Product Family No. H44130
108
in.
mm
in.
mm
1.900
2.510
63.75
1.620
42.42
2-1/16
2.510
63.75
1.620
42.42
2-3/8
2.905
73.79
1.990
50.55
2-7/8
3.781
96.04
2.313
58.75
3-1/2
4.531
115.09
2.938
74.63
Safety Joints
B Shear-Out Safety Joint
Product Family No. H44131
APPLICATION
The B™ shear-out safety joint is designed for use between the packer and the sand screen to provide
a means of releasing and retrieving the production string, should the screen become sanded in. It
may also be used in any application that includes the use of an upstrain-type releasing device.
SPECIFICATION GUIDE
Max OD
Nom ID
Size
2-3/8
in.
mm
in.
mm
3.094
78.59
1.929
49.00
2-7/8
3.719
94.46
2.438
61.93
3-1/2
3.844
98.55
3.064
77.72
4
4.340
110.24
3.428
87.12
4-1/2
5.031
127.79
3.900
99.03
7
8.531
216.69
6.250
158.75
B Shear-Out Safety Joint
Product Family No. H44131
C Rotationally Locked Shear-Out Safety Joint
Product Family No. H44132
APPLICATION
The C™ rotationally locked shear-out safety joint is a long-stroke shear release, which transmits
torque in its closed position. It has been speciically designed for use between packers in dual
completions and in selective completions using hydraulic/hydrostatic single-string packers. When
run above the upper packer in a single-string completion, the shear value should be adjusted to
compensate for any hydraulic conditions that exist when the string is landed or that will be created
by well-treating operations.
SPECIFICATION GUIDE
Max OD
Nom ID
Size
in.
mm
in.
mm
1.900
2.500
63.50
1.620
41.15
2-3/8
3.063
44.80
2.000
50.80
2-7/8
3.698
93.93
2.406
61.11
3-1/2
4.500
114.30
2.968
75.39
6-5/8
7.375
187.33
5.921
150.39
Shear-Out Safety Joint
Product Family No. H44130
109
Parallel Flow Systems
Model A Full-Opening Locator Parallel Flow Tube
Product Family No. H70001
Model A Full-Opening Anchor Parallel Flow Tube
Product Family No. H70010
Model A Full-Opening Anchor
Parallel Flow Tube
Product Family No. H70010
APPLICATION
The Model A™ full-opening parallel low tube is a locator-type tubing seal assembly containing two parallel low paths.
It is used in the upper packer of a two-packer parallel string installation. The long-string side is threaded both up and
down and the short-string side contains a sealbore. The head is machined to a funnel shape with the axis in line with
the sealbore so the parallel seal nipple can be guided into the bore. Since any seal movement would cause the seal to
leave the bore, suficient set-down weight must be available to prevent movement of the parallel low tube. The Model
A anchor parallel low tube is intended for use as a locator-type parallel low tube but is used when well conditions
require the tubing to be landed in tension or when insuficient tubing weight is available to prevent movement.
F Parallel Locator
Seal Nipple
Model A Parallel Anchor
Seal Nipple
Product Family No. H70202
Product Family No. H70301
APPLICATION
F™ is used to land a short string in the parallel
low tube. It incorporates only one seal stack, so
suficient tubing weight must be applied to prevent
seal movement.
APPLICATION
The Model A™ anchors and seals a short string in the
parallel low tube. It is used when well conditions
require that the short string be landed in tension or
where insuficient tubing weight is available to keep
the seals in the sealbore.
Model A Parallel Anchor Seal Nipple
Product Family No. H70301
F Parallel Locator Seal Nipple
Product Family No. H70202
F Parallel Snap-Latch Seal Nipple
Product Family No. H70701
APPLICATION
The F™ seal nipple, when landed in the short string side of the low tube, will snap past a shoulder in the lower end of
the bore. The snap-latch will hold suficiently to allow for a slight upstrain to provide an indication that the seal nipple is
positioned in the sealing bore. When used in conjunction with set-down weight, it provides an extra measure of safety but
does not, however, actually latch the seal nipple to the low tube. A set-down weight of 2,000–4,000 lb (907–1 814 kg) is
required to latch the seal nipple and a pull of 6,000–8,000 lb (2 721–3 628 kg) will remove it from the low tube.
SEAL NIPPLE SIZE AVAILABILITY GUIDE
F Parallel Snap-Latch Seal Nipple
Product Family No. H70701
110
Model
Product
Family
No.
Type
F
A
F
H70202
H70301
H70701
Locator
Anchor
Snap-Latch
1.25
x
1.53
x
x
Short String Sealbore
in.
1.68
1.96
x
x
x
x
2.28
x
x
x
2.5
x
x
Plugging Devices
E Hydro-Trip Sub
Product Family No. H79928
APPLICATION
The E™ Hydro-Trip Sub is used below a hydraulically actuated tool, such as a hydraulic-set packer, to
provide a means of applying the required tubing pressure for tool activation. The unique sub uses a
ball that seals on the seat. After the packer is set, increased pressure forces the ball seat down until
the ingers snap back into a groove. This fully opens the sub and the ball passes on down the tubing.
The E is available for use with 1.900-in.–4.500-in. (48.3-mm–114.3-mm) size tubing strings.
SPECIFICATION GUIDE
Ball Seat ID
Ball Size
Size
1.900
Before Shifting
in.
mm
in.
mm
in.
mm
1-7/16
25.4
1.250
31.8
1.516
38.5
1-1/2
38.1
1.375
34.9
1.860
47.2
1-3/4
44.5
1.625
41.3
1.906
48.4
2-3/8
2-7/8
After Shifting
2-1/8
53.0
2.000
50.8
2.375
60.3
2-1/2
63.5
2.312
58.7
2.781
70.6
3-1/2
2-3/4
69.9
2.500
63.5
2.953
75.0
3-1/16
77.8
2.734
69.4
3.615
91.8
3-3/8
85.7
2.985
75.8
3.865
98.2
4-1/2
E Hydro-Trip Sub
Product Family No. H79928
C Tubing Testing Sub
Product Family No. H59921
APPLICATION
The C™ tubing testing sub, along with a Bakerlite ball, may be used to test any tubing string. The sub’s
design includes a machined, 45-degree, tapered ball seat. The Bakerlite ball may be reverse-circulated
out of the tubing string after a test. In the event the tubing is faulty, the ball can be left in position and
the tubing tested as it is withdrawn from the well. The C is available for use with 2-3/8-in. to 4-1/2-in.
(60.3-mm to 114.3-mm) size tubing strings.
SPECIFICATION GUIDE
Ball Size
Max OD
Nom ID
Size
in.
C Tubing Testing Sub
Product Family No. H59921
2-3/8
mm
1-7/16
36.5
1-3/4
44.4
in.
mm
in.
mm
1.281
32.5
3.094
78.5
1.500
38.1
1-7/8
47.6
1.781
45.2
1-7/16
36.5
1.281
32.5
2-7/8
1-3/4
44.4
38.1
2-1/8
53.9
3-1/2
2-1/2
4-1/2
3-1/2
3.719
94.4
1.500
1.750
44.4
63.5
4.531
115.0
2.125
53.9
88.9
5.594
142.0
3.250
82.5
111
Plugging Devices
Silhouette
Product Family No. H41586
APPLICATION
The Silhouette packer setting tool is designed for interventionless setting of hydraulic packers.
The Silhouette tool has an upward opening lapper allowing self-illing of the tubing string
during deployment.
The Silhouette lapper is opened by applying pressure down the tubing string. This pressure will
shear a shear ring. Pressure may still be applied to the lapper to the required hydraulic packer
setting pressure. The lapper will permanently open once applied pressure is bled off. A spring
loaded inner sleeve pushes the lapper open and permanently locks it open.
Advantages
„„Allows
interventionless packer setting
proven Baker Hughes flapper technology from our OCRE™ portfolio
„„Mechanical closing, hydraulic opening
„„Provides self-filling of tubing string during completion deployment
„„Shear value can be adjusted, depending on the application
„„Provides large flow for reverse circulating
„„Provides full ID when flapper is opened
„„Sandy service qualified
„„5-1/2-in. (139.7-mm) tubing size currently available
„„Other sizes currently in the development process. Please consult your
Baker Hughes representative for further details
„„Uses
Silhouette
Product Family No. H41586
112
Plugging Devices
FLOGARD Single-Cycle Tool
Product Family No. H67116
APPLICATION
The FLOGARD™ single-cycle tool (SCT) is a circulating device that is operated hydraulically
from the surface using internal tubing pressure. Run in the hole in the open position, the
SCT allows the tubing string to self-ill. It also enables circulation to combat well control
problems and distributes lighter luid to create an underbalanced condition.
Advantages
„„Permits
auto-fill of the tubing above a barrier device such as the full-bore
isolation valve (FBIV)
„„Permits forward and reverse circulation
„„The number of open ports for circulation and shear screws may be varied from to
achieve desired closing rate
„„Locks closed permanently when actuated
„„Mechanical override available
„„High burst and collapse rating
„„May be used as a modular system with the FBIV where a barrier is required
FLOGARD Full-Bore Isolation Valve
Product Family No. H67121
The Single-Cycle Tool
Product Family
No. H67116
APPLICATION
The FBIV is a normally closed disc valve, designed to provide isolation within a tubing
string and hold pressure from both above and below. The FBIV is cycled open after a
predetermined number of pressure cycles to allow full-bore access through the tailpipe.
Advantages
„„Reliable
Metal Barrier–The FBIV’s solid metal barrier holds pressure from above
and below; barrier is opened nondestructively, ensuring reliable and
predictable opening
„„Versatility–Suitable for many completion applications, including temporary
abandonment; suitable for extended well test work with very low redress costs
„„Ease of Use–Valve opens on bleed-off cycle with instant full-bore access–no
waiting, no debris and no additional surface equipment required
„„Pressure Testing–Standard FBIV provides up to 12 pressure testing cycles;
pressure testing before setting the packer is possible with a multi-cycle tool
multi-cycle tool (MCT)
„„Modular System–FBIV can be used with or without the MCT, which enables selffilling of tubing and the facility to set packers externally
FLOGARD Full Bore
Isolation Valve
Product Family
No. H67121
Additional Information
The valve is mechanical and nondestructive; it provides a reliable and easily redressable
barrier for extended well testing, temporary suspension barrier and completion work.
113
Plugging Devices
SPECIFICATION GUIDES
The SIngle-Cycle Tool, Product Family No. H67116
Tool ID
Tool OD
Working Pressure
Temperature
Length
Tool Size
in.
mm
in.
mm
psi
bar
ºF
ºC
in.
mm
452 x 275
2.750
70
4.510
115
6,000
414
300
150
57
1.448
588 x 375
3.750
95
5.875
146
5,000
345
300
150
55
1.397
802 x 500
5.000
127
8.010
203
8,000
552
300
150
62
1.575
833 x 575
5.750
146
8.330
212
5,000
345
300
150
62
1.575
938 x 600
6.000
152
9.380
238
8,000
552
300
150
66
1.676
Full-Bore Isolation Valve, Product Family No. H67121
Tool ID
Working Pressure
Above
Tool OD
Tool Size
n
Working Pressure
Below n
Temperature
Length
in.
mm
in.
mm
psi
bar
psi
bar
ºF
ºC
in.
mm
452 x 275
2.750
70
4.515
114.7
10,000
689
8,000
552
300
150
120
3.048
588 x 375
3.750
95
5.88
149.4
8,000
552
8,000
552
300
150
124
3.150
802 x 500
5.000
127
8.010
203
8,000
552
3,000
207
300
150
135
3.429
834 x 575
5.750
146
8.34
238.5
7,500
517
3,000
207
300
150
133
3.378
939 x 600
6.000
152
9.39
238.5
8,000
552
3,000
207
300
150
141
3.581
If working pressure from below exceeds stated rating, contact Baker Hughes.
Mechanical Release Tool, Product Family No. H67115
Size X
X
114
Tool O/D Fingers Retracted
Tool O/D Fingers Deployed
Max Length
in.
mm
in.
mm
in.
mm
2.750
2.650
67
2.920
74
28.58
726.00
3.750
3.410
87
3.950
100
27.5
672.00
5.000
4.23
107.4
5.210
132
36.00
914.00
5.750
4.23
107.4
5.920
150
36.00
914.00
6.000
4.23
107.4
6.250
159
36.00
914.00
There must be no restrictions above the FBIV, which would prevent running of the contingency mechanical release tool.
Packer Extensions
Mill-Out Extension
Product Family No. H49941
APPLICATION
A mill-out extension can be run directly below a sealbore packer or sealbore extension. For
permanent packers, the mill-out extension is required to accommodate the mandrel and
catch sleeve of the CJ™ packer milling tool during packer milling. In the case of a retrievable
sealbore packer, the mill-out extension will accommodate the mandrel and catch sleeve of
the retrieving tool.
Mill-Out Extension
Product Family No. H49941
Sealbore Extension
Product Family No. H49940
APPLICATION
Sealbore extensions can be run below a sealbore packer. A sealbore extension is run to
provide additional sealing when a long seal assembly is run to accommodate considerable
tubing movement. The sealbore extension has the same ID as the corresponding packer
sealbore it is run with, thus all seals of a long seal assembly seal off in the sealbore
extension. If extreme tubing movement is anticipated, it is advisable to incorporate
some blank sections in the seal assembly to minimize the friction of the seals inside the
sealbore extension.
Sealbore Extension
Product Family No. H49940
115
P r o d u c t i o n S t r in g A c c e s s o r ie s
Blast Joint
Product Family No. H45750
APPLICATION
The blast joint, positioned opposite the perforations in the casing, is used in the tubing string of a
lowing well to protect it from the abrasive action of the lowing well. It exposes the maximum of metal
in the abrasive area, maintaining at the same time API tubing ID and coupling OD. It is available in 10-ft
(3.05-m) or 20-ft (6.10-m) lengths and for use with 2-3/8-in. (60.3-mm) through 4-1/2-in. (114.3-mm)
production strings.
Blast Joint
Product Family No. H45750
Perforated Spacer Tube
Product Family No. H45743
APPLICATION
The perforated spacer tube is used at the end of a tubing string to provide an alternate low path when
wireline measuring devices are used.
Flow Coupling
Perforated Spacer Tube
Product Family No. H45743
Product Family No. H81920
APPLICATION
Flow couplings are used to protect the integrity of tubing from erosive turbulence. They are also
used above and below a geometric restriction in the low path, depending on the well conditions. API
Recommended Practices 14B advises use of low couplings above and below safety valves. Baker Hughes
offers low couplings in 4-ft. (1.22-m), 6-ft. (1.83-m), 8-ft. (2.45-m) and 10-ft. (3.05-m) lengths to suit
the application.
Flow Coupling
Product Family No. H81920
116
P r o d u c t i o n S t r in g A c c e s s o r ie s
Wireline Entry Guide With Pump-Out Plug,
Shear-Out Ball Seat, and Shear-Out Ball Seat Sub
Product Family No. H46921, H79927
APPLICATION
The wireline entry guide is designed to be run on the bottom of the
tubing string. It will aid wireline tools’ re-entry into the tubing. The
wireline entry guide with pump-out plug, wireline entry guide with
shear-out ball seat and the shear-out ball seat sub are installed on the
bottom end of the tubing to allow the tubing string to be pressured.
When the differential pressure at the tool reaches a predetermined
value, the plug or ball and seat, are pumped out of the tool. After the
plug or ball seat have been pumped out, these subs allow unrestricted
access from the tubing into the casing below the tubing string. These
products are available in a variety of conigurations.
Wireline Entry Guide
Product Family No. H46921
Options include a muleshoe guide to facilitate easy entry when running
the tubing through the top of a liner or into a sealbore packer and
expendable check valves. The shear-out ball seat sub (Product Family
No. H79927) can be furnished in a box x pin coniguration for those
applications where it is necessary to run additional tubing or completion
equipment below the shear-out ball seat sub. Since each of these
tools expends a plug or ball and ball seat during their operation, it is
necessary to ensure those parts will safely pass through all equipment
that is located below them.
Wireline Entry Guide
With Pumpout Plug
Product Family No. H46921
Wireline Entry Guide
With Shear-Out Ball Seat Sub
Product Family No. H79927
117
Notes
118
Disclaimer of Liability: This information is provided for general information purposes only and is believed to be accurate as of the date hereof; however, Baker Hughes
Incorporated and its affiliates do not make any warranties or representations of any kind regarding the information and disclaim all express and implied warranties
or representations to the fullest extent permissible by law, including those of merchantability, fitness for a particular purpose or use, title, non-infringement, accuracy,
correctness or completeness of the information provided herein. All information is furnished “as is” and without any license to distribute. The user agrees to assume all
liabilities related to the use of or reliance on such information. BAKER HUGHES INCORPORATED AND ITS AFFILIATES SHALL NOT BE LIABLE FOR ANY DIRECT, INDIRECT,
SPECIAL, PUNITIVE, EXEMPLARY OR CONSEQUENTIAL DAMAGES FROM ANY CAUSE WHATSOEVER INCLUDING BUT NOT LIMITED TO ITS NEGLIGENCE.
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© 2012 Baker Hughes Incorporated. All rights reserved. 15056 REV.1 09/2012