Sand Control Systems

Transcription

Completions and Production
Sand Control Systems
Introduction
Baker Hughes has been the world leader in gravel pack solutions for nearly 30 years and in soft formation pumping services for over
20 years.
Many of the world’s oil and gas wells produce from unconsolidated sandstones that produce formation sand with reservoir fluids.
Problems that are associated with sand production include: plugging of perforation tunnels, sanding up of the production interval,
accumulation in surface separators, and potential failure of downhole and surface equipment from erosion. These problems
can pose serious economic and safety risks. Soft formation wells require specialized sand control completion practices to allow
hydrocarbons to be produced without formation sand.
While it is important to effectively prevent sand production, it is equally important to do so in a way that does not hinder a well’s
productivity. This dual goal drives Baker Hughes ongoing contributions to the design and development of completion solutions for
unconsolidated formations. Regardless of what is required, an openhole horizontal gravel pack, a high-rate frac pack, a cased-hole
gravel pack, acid stimulation, or a stand-alone screen completion, operators know they can depend on Baker Hughes for solutions
that are best-in-class.
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Alphabetical Product Index
Capabilities
Openhole Accessories
Design Software........................................................................... 4-5
Anti-Hydraulic Lock Seal Bore........................................................53
Manufacturing..................................................................................3
BetaBreaker Valve...........................................................................55
Physical Testing Laboratory..............................................................2
Gravel Pack Quick Connect.............................................................54
Research and Development Laboratory............................................2
Model GPV Set Shoe......................................................................53
Technical Support Laboratories........................................................2
Training..............................................................................................1
Cased Hole Accessories
Model A Ratcheting Muleshoe.......................................................60
Applications
Model GPR-6 and GPR-24 Shear-Out Safety Joint.........................57
Cased Hole Systems................................................................. 13-21
Model S-22 Anchor Seal Assembly................................................58
Non-Conventional Systems...................................................... 22-24
Model S-22 Locator Seal Assembly...............................................58
Openhole System........................................................................ 7-12
Model S-22 Multiple Acting Indicator Seal Assembly...................60
Model S-22 Seal Nipple.................................................................58
Packers
Model S-22 Snap-Latch Seal Assembly.........................................59
Double-Grip SC-LP Compression Packer.........................................36
Model S-22B Snap-Latch Seal Assembly.......................................59
Model D and DB Retainer Production Packer........................... 38-39
Model F-1 and FB-1 Retainer Production Packer...................... 40-41
Screens
Model HP-1 Packer.........................................................................34
BAKERWELD Screen.......................................................................61
Model R-3 Retrievable Casing Packer............................................35
EQUALIZER Screen..........................................................................65
Model SC-1 Gravel Pack Packer.....................................................30
EXCLUDER2000 Screen...................................................................63
Model SC-1 Thermal Gravel Pack Packer.......................................32
EXPress Screen...............................................................................64
Model SC-1L Isolation Packer.........................................................31
SLIM-PAK Screen............................................................................62
Model SC-1R Thermal Gravel Pack Packer.....................................32
Model SC-2 Packer.........................................................................33
Service Tools
Models SC and HP Packers–Specification Guides................... 25-29
Closed Port Hydraulic Setting Tool.................................................73
Slips and Button Range–Specification Guide................................37
FASTool (Flapper Anti-Swabbing Tool)...........................................70
Model A Multiple Acting Indicator Collet......................................71
Gravel Pack Extensions
Model A SMART Collet
Model CK FRAQ Extension..............................................................44
(System Multi-Acting Repositioning Tool).................................70
Model CS Openhole Gravel Pack Extension–Application..............43
Model B-1 Hydraulic Setting Tool . ................................................72
Model S Gravel Pack Extension with Sliding Sleeve.....................45
Model BSC-R Gravel Pack Crossover Tool......................................69
Model S Perforated Gravel Pack Extension....................................45
Model BSC-R Hydro-Set Adapter Kit..............................................74
Model CK Crossover Tool................................................................67
Fluid Loss Control Devices
Model CS Crossover Tool................................................................67
BAKERWELD Select-A-Flow II Screen............................................51
Model CS-AP Crossover Tool..........................................................67
Fluid Loss Control Valve (FLCV).......................................................49
Model HP Hydraulic Setting Tool....................................................73
Isolation Tool and Retrieving Tool...................................................48
Model S-1 Retrieving Tool..............................................................77
Model C Knock-Out Isolation Valve................................................47
Model S-1 Shifting Tool..................................................................75
Model RB Isolation Valve................................................................52
Model S2H Hydro-Set Adapter Kit.................................................74
SAF-1 Valve.....................................................................................50
Model S2P and S2PH Crossover Tools............................................68
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Model SB Latching Type Packer Plug..............................................76
Auxiliary Support Equipment
Model SB Latching Type Packer Plug With Support Mandrel
720 GAL Acid Tank........................................................................105
and Surge Chamber...................................................................76
3,000 LB Sand Tote Tank...............................................................105
Model SC Hydraulic Setting Tool....................................................72
Slurry Dehydrator With Diaphragm Pumps..................................105
Models SC and HP Packers–
Packer Size/Accessory Size Guide....................................... 78-79
Over the Top Gravel Pack Service Tool...........................................75
Data Acquisition
BDAQ 9000NT Real-Time Data Acquisition System............. 108-109
BDAQ 8000NT Data Acquisition System......................................110
Tubing-Conveyed Perforating
Remote Treatment Monitoring (RTM)...........................................107
High Density Perforating Guns.......................................................81
Horizontal Oriented Perforating System (HOPS) . ..........................84
Fracturing Fluid Systems
Model F Firing Head........................................................................83
BoraFRAQ Systems.......................................................................113
PERFFORM Charges........................................................................82
Crosslinked Frac Pack And Gravel Pack Fluid Systems................113
StimGun Assembly . .......................................................................85
Diamond FRAQ..............................................................................112
Emerald FRAQ....................................................................... 113-114
Pressure Pumping Equipment
Fraq Paq Fluid Systems.................................................................111
Marine Vessel.................................................................................87
Ruby FRAQ ...................................................................................115
MV RC Baker............................................................................. 88-89
Surfactant Frac Pack and Gravel Pack Fluid Systems...................111
SC 600 Triplex Pump.......................................................................93
SurFRAQ........................................................................................111
SC 1200 Triplex Pump.....................................................................92
SC 2000 Triplex Pump.....................................................................91
Gravel and Proppants
Skid-Based Pumping Equipment.....................................................90
Baker Low Fine Gravel..................................................................117
Ceramic Gravel or Proppant..........................................................117
Fluid Mixing
Fracturing Proppants and Sand Control Gravel............................117
27-BBL Batch Mixer......................................................................100
Resin Coated Gravel or Proppant..................................................117
100-BBL Batch Mixer ...................................................................101
Chemical Additive System (CAS Unit)............................................98
Acid Systems
Gravel Infuser..................................................................................97
HTO Acid.......................................................................................119
Hi-Rate Gravel Infuser....................................................................97
Hydrochloric Acid..........................................................................119
Model 30 Fraq Blender...................................................................96
Hydrofluoric Acid...........................................................................119
Model 60 Fraq Blender...................................................................95
Organic Acids................................................................................119
Twin 13-BBL Batch Mixer................................................................99
Typical Acid Systems....................................................................120
Twin 100-BBL Batch Mixer ..........................................................102
Chemical Additives
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Fluid Filtration
Acid Corrosion Inhibitors..............................................................121
Dual Acid Filter.............................................................................104
Acid Gelling Agents .....................................................................124
Vertical-Leaf Filtration System.....................................................103
AG-193 .........................................................................................124
Biocides . ......................................................................................126
Fluid Loss Control Systems and Materials
Chemicals for Acid and Fracturing Fluid Systems........................121
B-641Q .........................................................................................128
CI-100............................................................................................121
Baker Clean Gel I..........................................................................127
CI-105............................................................................................121
Bridging Agents............................................................................128
CI-200............................................................................................121
BS-648...........................................................................................128
CII-101...........................................................................................121
FLC-306.........................................................................................128
CII-107 ..........................................................................................121
FLC-309.........................................................................................128
Clay Stabilizers ............................................................................125
Mil-Carb........................................................................................128
Corrosion Inhibitor Intensifiers.....................................................121
Mini-Carb......................................................................................128
CS-7 . ............................................................................................125
OMNIFLOW DIF.............................................................................127
CSC-6 ...........................................................................................125
PERFFLOW DIF..............................................................................127
EC9555A . .....................................................................................126
PERFFLOW 100..............................................................................127
FE-120 ..........................................................................................123
Permanent Blocking Agents..........................................................128
FE-120L..........................................................................................123
PoroPlug................................................................................ 128-129
FE-123...........................................................................................123
W-308............................................................................................128
FE-125L..........................................................................................123
FE-400...........................................................................................123
Hole/Casing Cleaning Systems and Chemicals
Foaming Agents ...........................................................................126
CASING WASH 100......................................................................131
Friction Reducing Agent................................................................126
CASING WASH 200......................................................................131
Iron Control Agents.......................................................................123
DOPE-FREE....................................................................................134
Magnacide 575 ............................................................................126
DOPE-FREE ZN..............................................................................134
MS-77...........................................................................................124
FLOW-CLEAN................................................................................131
MS-90...........................................................................................124
FLOW-CLEAN R.............................................................................132
MS-100 ........................................................................................124
FLOW-CLEAN SS...........................................................................132
Mutual Solvents............................................................................124
FLOW-SURF...................................................................................132
NE-100..........................................................................................122
FLOW-SURF PLUS ........................................................................132
NE-110..........................................................................................122
Hole Cleaning Systems.................................................................131
NE-120..........................................................................................122
MS-90...........................................................................................133
Scale Inhibitors.............................................................................125
Pipe Pickling Systems and Chemicals..........................................134
SI-203............................................................................................125
Prop FLUSH...................................................................................135
SI-352............................................................................................125
ST-100...........................................................................................122
Appendix
ST-101...........................................................................................122
Appendix............................................................................... 137-161
Surfactants (Surface Acting Agents)............................................122
WF-117..........................................................................................126
X-Cide 207.....................................................................................126
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Product Number Index
Product
Family No.
Description
H30178
BetaBreaker Valve......................................... 55
H48605, H48606, BAKERWELD Screen..................................... 61
H41306, H41308
Model F-1 and FB-1 Retainer
H48634, H48645,
and H41340
H41505, H41525
and H41513
Page
Production Packer.................................... 40
Model D and DB Retainer
Production Packer.................................... 38
Product
Family No.
Description
Page
H48646 and
H48647
H48619
SLIM-PAK Screen.......................................... 62
Model GPR-6 and GPR-24 Shear-Out
H44450
Model S-22 Locator Seal Assembly............. 58
H48659 and
H44451
Model S-22 Anchor Seal Assembly.............. 58
H48661
Safety Joint.............................................. 57
H44452
Model S-22 Snap-Latch Seal Assembly....... 59
H48674
BAKERWELD Select-A-Flow II Screen.......... 51
H44453
Model S-22 Seal Nipple............................... 58
H48678
EQUALIZER Screen........................................ 65
H44454
Model S-22 Multiple Acting
H48690 and
EXCLUDER2000 Screen................................. 63
Indicator Seal Assembly.......................... 60
H48691
H44456
Model S-22B Snap-Latch Seal Assembly..... 59
H48695
EXPress Screen............................................. 64
H44458
Model A Ratcheting Muleshoe..................... 60
H48705
Model S Perforated Gravel Pack Extension.. 45
H44520
Model B-1 Hydraulic Setting Tool................. 72
H48706
Model S Gravel Pack Extension
H44521
Model SC Hydraulic Setting Tool.................. 72
H44534
Model A Multiple Acting Indicator Collet.... 71
H48714
Model CK FRAQ Extension............................ 44
H44540
FASTool (Flapper Anti-Swabbing Tool)......... 70
H48716
Model CS Openhole Gravel Pack Extension. 43
H44549
Model S2H Hydro-Set Adapter Kit............... 74
H48732
Model S-1 Shifting Tool................................ 75
H44559
Closed Port Hydraulic Setting Tool............... 73
H48735
Model C Knock-Out Isolation Valve.............. 47
H44566 and
Model S2P and S2PH Crossover Tools.......... 68
H48735SP
Isolation Tool . .............................................. 48
H48736
Model GPV Set Shoe.................................... 53
H44572
with Sliding Sleeve.................................. 45
H44567
Model BSC-R Hydro-Set Adapter Kit............ 74
H48751
SAF-1 Valve................................................... 50
H44573
Model BSC-R Gravel Pack Crossover Tool.... 69
H48753
Model RB Isolation Valve.............................. 52
H44577
Model CK Crossover Tool.............................. 67
H48803
Model SC-1L Isolation Packer....................... 31
H44578, H48716
Model CS Crossover Tool.............................. 67
H48807
Model SC-2 Packer....................................... 33
H48816
Model HP-1 Packer....................................... 34
and H48717
H44587
Model HP Hydraulic Setting Tool.................. 73
H48820
Model SC-1 Gravel Pack Packer................... 30
H44588
Model CS-AP Crossover Tool........................ 67
H48829
Double-Grip SC-LP Compression Packer....... 36
H44591
Model A SMART Collet (System
H48853
Model S-1 Retrieving Tool............................ 77
H48853SP
Retrieving Tool.............................................. 48
Multi-Acting Repositioning Tool)............. 70
H48158
3,000 LB Sand Tote Tank............................. 105
H48864
Model SC-1R Thermal Gravel Pack Packer... 32
H48330
Over the Top Gravel Pack Service Tool......... 75
H48866
Model SC-1 Thermal Gravel Pack Packer..... 32
H48506
Gravel Pack Quick Connect........................... 54
H48915
Twin 13-BBL Batch Mixer.............................. 99
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Product Number Index
Product
Family No.
Description
Product
Family No.
Description
H48927
720 GAL Acid Tank...................................... 105
H49069
Friction Reducing Agent.............................. 126
H48953
Slurry Dehydrator With Diaphragm Pumps.105
H49072
Foaming Agents.......................................... 126
H48979
Twin 100-BBL Batch Mixer.......................... 102
H49150
BDAQ 8000NT Data Acquisition System.... 110
H48986 and
27-BBL Batch Mixer.................................... 100
H49163
SC 1200 Triplex Pump................................... 92
H49173
SC 2000 Triplex Pump................................... 91
Page
H48987
H48988
SC 600 Triplex Pump..................................... 93
H49174
Model 60 Fraq Blender................................. 95
H48989
Dual Acid Filter........................................... 104
H49175
Chemical Additive System (CAS Unit).......... 98
H48991
BDAQ 9000NT Real-Time Data
H49204
Baker Low Fine Gravel................................ 117
H49205
Resin Coated Gravel or Proppant................ 117
Acquisition System......................... 108-109
H48994
100-BBL Batch Mixer.................................. 101
H49211, H49212, Ceramic Gravel or Proppant........................ 117
H48995
Vertical-Leaf Filtration System................... 103
H49214 and
H49015
Clay Stabilizers........................................... 125
H49225
H49017
Hydrochloric Acid........................................ 119
H49220
PERFFLOW DIF............................................ 127
H49019
Hydrofluoric Acid......................................... 119
H49357
Model F Firing Head...................................... 83
H49021
HTO Acid..................................................... 119
H49371
Horizontal Oriented
H49021
Corrosion Inhibitor Intensifiers................... 121
H49037
Organic Acids.............................................. 119
H49372
StimGun Assembly........................................ 85
H49038
Acid Corrosion Inhibitors ........................... 121
H64101
Model R-3 Retrievable Casing Packer-
H49039 and
Surfactants (Surface Acting Agents).......... 122
Perforating System (HOPS)...................... 84
Single Grip............................................... 35
H64201
H49066
Model R-3 Retrievable Casing PackerDouble Grip.............................................. 35
H49043
Mutual Solvents.......................................... 124
H49044
Iron Control Agents..................................... 123
H66517, H66519 Model SB Latching Type Packer Plug and
H49058
Scale Inhibitors........................................... 125
and H66520
H49059
Biocides....................................................... 126
H49060
Crosslinked Frac Pack And
H49069
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Page
Model SB Latching Type Packer Plug With
Support Mandrel and Surge Chambe...... 76
H68433
Fluid Loss Control Valve (FLCV)..................... 49
Gravel Pack Fluid Systems..................... 113
H98959
Gravel Infuser................................................ 97
Acid Gelling Agents.................................... 124
H99563
Anti-Hydraulic Lock Seal Bore...................... 53
Capabilities
Reservoir Optimized Completion Philosophy
Staying competitive in today's market requires innovation and a
willingness to provide the customer with cost effective solutions
that optimize reservoir productivity and recovery, minimize risks,
and provide operational excellence. Baker Hughes takes this
challenge to heart and has continued to invest in both hardware
and technology necessary to globally advance the sand control
industry. For over 30 years, Baker Hughes has been recognized
as the world leader in soft formation gravel pack technology
and continues this leadership with commitment to the customer
to deliver innovative completion solutions. This commitment
is shown through the advancement of sand control completion
equipment including downhole tools, fluids and proprietary
planning software for frac pack completions; leadership in
the gravel packing of long horizontal wells; advanced screen
technology and continued expansion of high horsepower pumping
equipment and offshore pumping vessels. It is this proactive role
in technology and process development that allows Baker Hughes
the ability to provide the optimum sand control solution, no matter
what the application.
To assist our customers in identifying the most effective sand
control techniques, the Baker Hughes sand control systems group
makes use of reservoir analysis, geologic data, and in-depth
knowledge of the processes involved with the installation of
effective sand control completions. Use of these tools help to
identify “Best Fit” sand control and completion systems that
maximize the overall return on investment to the customer.
This process requires Baker Hughes to be involved early in
the completion and drilling design phases. Earlier involvement
provides the opportunity to utilize integration and communication
between all Baker Hughes companies to achieve the desired goals
of the operating company.
Training
As the first step in providing the highest level of sand control
solutions, Baker Hughes is dedicated to providing our personnel
with continuous training opportunities. Through specialized
training at the Baker Hughes education center in Houston, Texas,
and the regional training centers in Aberdeen, Scotland and
Maricaibo, Venezuela, the latest in sand control technology,
and time-proven best practices are passed on to field, sales
and engineering personnel. In addition, our team-effort with our
customers is further enhanced by seminars on both specific areas
of interest and in general sand control technology.
Laboratory Support Facilities
A key aspect to effective completion design is accurate
understanding of the reservoir and bounding formations. To gain
this understanding, Baker Hughes makes use of industry leading
technical support, research and development, and physical testing
laboratory facilities.
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Capabilities
Technical Support Laboratories
With laboratories located worldwide, Baker Hughes sand
control technical services laboratories provide support for
worldwide sand control operations, and testing required for
product line development. We are able to provide a variety of
services that help to optimize the completion process. These
laboratories provide testing for all aspects of sand control.
Testing capabilities include, but are not limited to, formation
evaluation for gravel pack sand selection, fluid compatibility
studies, emulsion tendencies, fluid rheology, return permeability,
fluid loss pill formulation, screen plugging evaluation, water
analysis, unknown identification, mineralogy determination, and
shale stability studies.
Physical Testing Laboratory
With laboratories located worldwide, Baker Hughes sand
control technical services laboratories provide support for
worldwide sand control operations, and testing required for
product line development. We are able to provide a variety of
services that help to optimize the completion process. These
laboratories provide testing for all aspects of sand control.
Testing capabilities include, but are not limited to, formation
evaluation for gravel pack sand selection, fluid compatibility
studies, emulsion tendencies, fluid rheology, return permeability,
fluid loss pill formulation, screen plugging evaluation, water
analysis, unknown identification, mineralogy determination, and
shale stability studies.
Research and Development Laboratory
Baker Hughes fluids research laboratory offers a wide variety of
testing capabilities to develop engineered solutions to the most
critical well completion and production problems. By directing
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primary attention on the interaction between unconsolidated
formations and stimulation fluids, hydrocarbon productivity can
be optimized.
Capabilities
Through close coordination with technical services laboratories
and engineering support teams, implementation of new
developments is streamlined in order to make the latest
advancements usable for customers sooner. Whether it is new
fluids development, or basic rock mechanics research into
the physics of hydraulic fracturing, our focus on soft, highpermeability formations, leads to the best match of technology
to application.
Manufacturing
Houston Navigation Facility
The Navigation facility is the industry’s leading designer and
manufacturer of downhole completion products including
completion and service packers and their associated components,
sand control completion systems, flow control products, remedial
and stimulation products and downhole instrumentation.
Manufacturing is a core competency of Baker Hughes. Our
machine shop fills more than 140,000 square feet with an
additional 110,000 square feet allocated to warehouse, assembly,
and test. The remaining 80,000 square feet is office space.
The Navigation facility has more than 90 modern machine
tools, less than five years old. Most of these tools are computer
controlled, many with the capability of state-of-the-art
conversational controls for fast, accurate and repeatable output.
We sustain this significant investment with a comprehensive
rebuilding and preventive maintenance program.
Dubai Screen Manufacturing Plant
The Baker Hughes Dubai screen manufacturing plant brings
unmatched sand control experience and the highest performance
levels to screen technology to help operators reduce intervention
costs in tough drilling environments, whether in deepwater,
extended reach, high pressures or unconsolidated sands.
The Dubai plant is the primary hub for Baker Hughes to produce
and distribute premium sand control screens and inflow control
solutions worldwide. From this central location, Baker Hughes:
 Innovates
game-changing technologies to lead the industry
in completions services that continually improve your
completions efforts
 Manufactures quality screen and inflow control products with
industry-leading gauge tolerances, extended screen life, and the
reliability downhole you require
 Optimizes design and manufacturing processes to improve tool
creation, modification, testing, and delivery for your specific
project requirements
 Responds rapidly to your manufacturing and delivery needs
worldwide, especially in Africa, Asia, Europe, the Middle East
and UK
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Capabilities
Design Software
As part of the effort to bring technology to our field operations,
Baker Hughes has developed several industry leading software
packages. First, for frac pack operations, Baker Hughes
is the only service company to provide a crossover tool
wear prediction package (XOTLive™) as well as a downhole
hydraulics program specifically designed to calculate the
forces acting on a crossover tool during all phases of a frac
pack operation (XOTMove™). When these packages are used
in concert with industry-leading hydraulic fracture numerical
models, frac pack designs and procedures can be effectively
optimized to provide highly effective completions.
Horizontal Departure (ft)
0
2,000 4,000 6,000 8,000
In addition to frac pack design, Baker Hughes has also used
its unsurpassed understanding of the horizontal gravel packing
process and downhole hydraulics and tool design to develop
XOTPaq™. This package combines horizontal gravel pack
modeling software with torque and drag calculations and
crossover tool hydraulic calculations to provide an extremely
accurate and practical design package.
Buckling Limits and Axial Loads (lbs)
-100,000
-50,00
0
50,000
100,000
0
150,000
0
No Buckling
Lateral
Helical
2,000
2,000
4,000
Set-Down Weight is
38000 lbs
6,000
Set-Down Weight (lbs)
6,000
8,000
10,000
8,000
12,000
10,000
12,000
XOTMove - workstring load analysis output
XOTLive - Detailed wear profiles based on full-scale testing
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Set-Down on Pkr
DataFrac
Treat (Circ)
Screen-out (Circ)
Lateral Buckling
Helical Buckling
14,000
16,000
Measured Depth (ft)
True Vertical Depth (ft)
4,000
Capabilities
Design Software
Critical Parameters
Fluid loss: 11074%
Bit size: 8.5 in.
Exp. hole dia: 9.18 in.
Screen OD: 5.5 in.
Washpipe OD: 4 in.
Fluid vis: 1cP
Fluid density: 9.8 ppg
Mix ratio: 1 ppga
Pump rate: 8.01 bpm
Frac gradient: 0.644 psi/ft
Prop size: 20/40
Prop density: 22.78 ppg
Proppant volume below packer:
16,500 lb (161 ft3)
Proppant volume at screen-out:
24,600 lb (241 ft3)
Dune height ratio (min): 0.729
Dune height ratio (min): 0.795
XOTPaq™
ALPHA wave - dune height profiles
Pump Pressure and Dune Height Ratio
0.90
5,000
0.85
4,000
0.80
3,000
2.75
2,000
0.70
1,000
0.65
0
0
10
20
30
40
50
60
70
80
Dune Height Ratio
Pressure (psi)
100% Pack
6,000
0.60
Pump Time (minutes)
Dune Height Ratio
Surface Pressure
Frac Pressure at Shoe
Hydrostatic at Shoe
Circulating at Shoe
Pump pressure and dune height ratio
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Openhole Systems
SC Setting Tool
SC-R Type Packer
GP Sliding Sleeve
CS Crossover Port
Seal Bore Sub
Model CS-300 Openhole Gravel
Pack System
For most open holes drilled in unconsolidated formations, a gravel
pack is the preferred completion option. By filling the annulus
between the screen and open hole with specially sized, high
permeability gravel pack sand, the wellbore is stabilized to control
production of formation sand and protect the screen from plugging
or erosion. When performed with proper procedures and tools,
openhole gravel packs can be highly productive and long lasting
completions. To maximize success, the open hole must be drilled
with a specialized drill-in fluid. The well must then be thoroughly and
rigorously cleaned by circulating completion brine and selected pills
at high rates leaving only the filter cake intact on the borehole walls.
The screen assembly is then deployed below the patented CS-300™
open hole gravel pack system. This system is designed specifically
for openhole gravel pack completions and ensures that hole stability
is maintained during screen deployment, packer setting, and gravel
packing by allowing hydrostatic pressure to be maintained on the
filter cake at all times. When it is desired to either place acid or
inflate ECP's™ (External Casing Packers) immediately following
an openhole gravel pack, the standard CS™ crossover tool can be
replaced with the CS-AP™ crossover tool.
Openhole gravel packing is applicable to short and long intervals (up
to several thousand feet) with well deviations ranging from vertical
to horizontal. Baker Hughes’ proprietary design software is used to
ensure the gravel pack is successfully placed in the well.
FASTool™
S-1 Shifting Tool
Indicating Coupling
SMART Collet™
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Openhole Systems
Stand-Alone Screen Installations
SC-R Type Packer
Milling Extension
Crossover Sub
Blank Pipe
EXCLUDER Screen
In certain applications, a stand-alone screen placed in an open
hole provides a simple and effective sand control completion in
unconsolidated formations. To maximize longevity and success,
stand-alone screen completions should only be applied in clean,
homogeneous sandstones with large well-sorted sand grains. The
screen must be capable of filtering the larger formation sand particles
and promote establishment of a permeable natural gravel pack. In
addition, a screen with maximum inflow area, like the EXCLUDER2000™
screen should be selected. Zonal isolation for water shutoff or
hydrocarbon production management may be achieved by using
packers in the open hole in conjunction with screens.
Each component of the EXCLUDER2000 has been designed to provide
the highest performance in a standalone screen application. The
shroud's smooth exterior design protects the screen from damage
during deployment in the open hole. The unique vector weave
membrane with uniform pore openings and large inflow area resists
plugging and erosion, increasing well longevity. Supporting the
vector weave is a BAKERWELD™ screen jacket that provides backup
filtration and adds tremendous collapse strength. The manufacturing
system used to construct the screen combines the various layers so
they act as one yielding a very mechanically strong product capable
of withstanding the rigors of a stand-alone screen completion.
Prior to placing a screen downhole, the well should be displaced
to a clear fluid or highly conditioned mud to minimize the amount
of solid particles that could lead to screen plugging. Typically the
screen is deployed under a rotationally locked Model SC-1R™ packer.
The rotational lock feature allows rotation of the screen assembly
in the event it becomes stuck during run-in. An o-ring seal sub and
Model GPV™ set shoe can be incorporated into the hookup to provide
circulation out the end of the screen to assist in screen deployment
or for use in spotting of filter cake breaker fluids in the open hole.
Note: A stand-alone screen completion should not be used in a cased
hole production well unless the perforation tunnels are prepacked with
a highly permeable media such as gravel pack sand. Not prepacking
the tunnels may result in them filling with formation sand. Filling of the
perforation tunnels with formation sand limits inflow area and results
in a high pressure drop across the completion. Cased holes requiring
sand control in most cases, should be gravel packed.
Seal Sub
Pup Joint
GPV Set Shoe
8
Openhole Systems
Use of External Casing Packers (ECP’s) and BetaBreakers
for Zonal Isolation With a Gravel Pack
SC-R Type Packer
Baker Hughes has developed the BetaBreaker™ technology to allow the incorporation of either
inflatable External Casing Packers (ECP's™) or Mechanical Actuated Openhole Packer (MPas™)
into a horizontal gravel pack completion. In order for the packers to seal against the formation,
gravel placement around the packer must be restricted. Considering the horizontal well alphabeta wave gravel deposition process achieved with low viscosity carrier fluids, the alpha wave
around the packer can be reduced to zero height by pumping sufficiently fast (approximately
300 ft/min [91.4 m/min] ) in the annulus between the packer and the hole. To cause the beta wave
to skip the packer, requires changing the return flow path from the end of the washpipe to a point
above the packer. The BetaBreaker is a differential pressure actuated circulating valve incorporated
into the washpipe of a gravel pack assembly. The tool is equipped with molded seals and must be
spaced-out to seal in a seal bore receptacle (incorporated into the screen assembly) immediately
above the packer when the gravel pack crossover tool is in the circulating position. Use of the tool
has no effect on the alpha wave depositional process. As the beta wave approaches the packer
position and covers the screen below the packer, the seal on the BetaBreaker blocks the normal
return flow path down the washpipe/screen annulus. This results in a mini screenout below the
packer. The screenout increases pressure in the washpipe/screen annulus above the BetaBreaker
tool. At approximately 150-200 psi (1.03-1.4 MPa), the spring force in the BetaBreaker is
overcome and the tool shifts open to divert returns into the washpipe above the packer. By
pumping at sufficiently high rates to eliminate the alpha wave and incorporating the BetaBreaker
tool in the washpipe, a “void” in the gravel pack is created around the packer allowing it to seal
against the formation.
Screen
Screen
ECP/MPas
Gravel Pack Sand
ECP/MPas
Screen
GPV
Set Shoe
Seal Sub
9
Openhole Systems
Use of ECP’s for Zonal Isolation
Without a Gravel Pack
Milling Extension
SC-R Type Packer
EXCLUDER Screen
Zonal Isolation Packer
Blank Pipe
Zonal Isolation Packer
EXCLUDER Screen
O-ring Seal Sub
GPV Set Shoe
10
Flow control in long openhole wells completed with a stand-alone
screen is difficult to achieve due to the open annulus between
the borehole and the screen. A solution to the problem is the use
of External Casing Packers (ECP's™). The ECP's break up the long
openhole section into smaller intervals to allow more meaningful
production log analysis and the potential for future zonal isolation.
The ECP's used can be conventional inflation type ECP's or the new
Baker Hughes MPas™ mechanically actuated openhole packer. To
achieve optimum results, the ECP's should be positioned to seal
across geologic reservoir boundaries (i.e., shale breaks or low
permeability streaks). A gauge hole improves sealing and longevity
of the packer. If inflatable packers are used, they can be inflated
with either brine or cement using seals or a cup tool to straddle
the inflation ports. If cement is used, the Baker Hughes HIT™ tool
technology is recommended to isolate the cement inside the
workstring and prevent contamination of the screen. By including
BetaBreaker™ valves in the washpipe, positive zonal isolation can
be obtained with a gravel pack.
Openhole Systems
EXPress Screen System
SC Setting Tool
Hydro-set
Adapter Kit
Type B
Casing Spear
Expansion Joint
20 ft (6.1 m)
The EXPress™ screen was developed to create an effective
sand control device that can be expanded to a larger OD and
ID once downhole thus greatly reducing or eliminating the
annular space between the screen and the wellbore. Although
there are many advantages to this type of screen it's greatest
potential is seen in horizontal openhole sand control.
By expanding screen in a horizontal open hole the annulus
between the screen and the formation can be greatly reduced
or even eliminated. Reduction of the annulus means greater
resistance to flow along the annulus and therefore production
flow is reduced on the exterior of the screen and increased
on the interior. The reduction in exterior flow means lower
velocities near the wellbore and therefore less sand
transportability and less erosional effects.
Expansion can also aid in formation stability by physically
supporting the formation if the screen is expanded until it is
touching the formation. This support in turn could prevent the
collapsing of the formation when the pressure in the wellbore
is reduced.
Swage Holder Bushing
Expansion Cone
Blank Pipe
Drillpipe
+/- 500 ft (158 m)
Casing Packer
EXPress Screen
Millout Extension
Circulating Valve
FORMpac XL Packer
(Openhole)
EXPress Screen
Expansion Cone
Pusher
Expansion Cone
To offer greater assurance of annular flow restriction Baker
Hughes offers the FORMpac™ XL expandable openhole barrier.
The unique element design delivers excellent expansion
performance that has been successfully tested to 1,000 psi
(6.9 MPa) differential pressure at 250°F (120°C). Baker Hughes
utilizes a simple hydraulic expansion joint and mechanical anchor
system to expand EXPress screen and FORMpac XL barriers.
This system operates independent of pipe weight and therefore
is not problematic in long lateral sections. Application of less
than 5,000 psi (34.5 MPa) down the workstring creates enough
force on the expansion cone to yield the EXPress screen material
causing expansion.
EXPress Screen
Bull Plug
Running In
Expanding
11
Openhole Systems
EQUALIZER Screen
Casing Packer
Blank Pipe
The EQUALIZER™ flow regulation system is a revolutionary production enhancement device
that combines the field-proven EXCLUDER2000™ premium screen technology for superior
sand control and a unique inflow control device which extends well longevity by delaying
water or gas coning in long horizontal wells. Additionally, the inflow control devices' ability
to greatly reduce annular flow further enhances the products sand control capability.
Through the use of computer modeling based on operator-supplied formation data, the
EQUALIZER system is configured with the optimum combination of cross-sectional area,
number of flow channels, and lengths of flow channels to provide the most effective
pressure drop versus varying flow rate characteristics to balance well inflow from a
particular formation. The system is applicable in a variety of situations, including:
 Horizontal wells with high PI to delay the water front or gas coning as well as
boosting production from the toe of the lateral section and low permeability zones
 Horizontal water injectors for more evenly distributed pressure profiles
 High viscosity crude
 Multilateral wells for optimizing branch flow
 Close proximity to water/gas caps
EQUALZER/
EXCLUDER2000 Screen
EQUALZER/
EXCLUDER2000 Screen
Gravel Set Shoe
Seal Sub
12
Cased Hole Systems
CK FRAQ System
Setting Tool
The CK FRAQ™ system is a high performance cased hole completion
system for frac pack sand control applications. The system
incorporates downhole tool components designed specifically for
extreme fluid velocities and high proppant volumes, as well as job
planning and execution computer software.
 Available for casing sizes from 5 in. (127 mm) to 9-5/8 in. (244.5 mm)
SC-R Type Packer
 Designed
FRAQ Port
FRAQ Sleeve Extension
Evacuation Port
for high treating pressures and high pump rates
 FRAQ extension features enhanced wear life and casing protection
 Crossover tool FRAQ port design is optimized for wear life
 Unique crossover tool evacuation position enhances proppant
cleanup by facilitating debris removal from inside of the
FRAQ extension
 Seal design and configuration minimizes crossover tool drag
 Positive indication of all crossover tool positions
 Crossover tool can be configured as a pressure tight conduit
through the service tool string allowing off-bottom circulation
 SMART Collet™ facilitates crossover tool positioning and
tool position maintenance with applied down-weight during
pump-in operations
 FASTool™ prevents formation fluid swabbing due to crossover tool
manipulation, provides zonal isolation while reverse circulating
for proppant cleanup, and facilitates pressure decline analysis for
fluid efficiency calculations
planning and execution computer software includes:
• XOTLive™ - accurately predicts FRAQ port operating envelope
 Job
for specific treatment designs
• XOTMove™ - crossover tool movement program determines
tool behavior and requirements for successful job execution
for specific well parameters and treatment designs
FASTool
Indicating Coupling
Shifting Tool
Indicating Coupling
SMART Collet
Multiple Acting
Indicating Collet
13
Cased Hole Systems
Closed Port
Hydraulic Setting Tool
Sc-Type Packer
FRAQ Port
FRAQ Sleeve
Evacuation Port
Seal Bore Sub
FASTool
SMART Collet
Model A indicating Collet
K.O.I.V.
Screen
SC-LP Compression Packer
Ported Disc Sub
Model F Firing Head
Perforating Gun
14
PERF-FRAQ System
The Model CK™ PERF-FRAQ™ system is a high performance one-trip
perforating and frac packing completion system optimized for today’s
advanced sand control technologies. Part of the Baker Hughes
CK FRAQ™ tool platform, the system is specifically designed to reduce
completion time and expense, minimize formation exposure to fluid
damage, and enhance well control. The one-trip system maintains
the same high performance ratings and features as the standard
CK FRAQ system.
The CK PERF-FRAQ system consists of a Baker Hughes TubingConveyed Perforating gun assembly, the Model SC-LP™ double-grip
packer, a Baker Hughes screen and liner assembly, and the CK FRAQ
tool assembly with additional closed port hydraulic setting tool.
Cased Hole Systems
Multiple Zone Stack Gravel Pack System
SC-Type Packer
Hi-rate Gravel
Pack Extension
Knock-out
Isolation Valve
EXCLUDER Screen
SC-Type Packer
Hi-rate Gravel
Pack Extension
EXCLUDER Screen
Snap-latch
Seal Assembly
Sump Packer
The Baker Hughes multiple zone stack gravel pack system is a
common sand control completion approach when two or more
producing intervals are encountered in the well. The system starts
by setting a sump packer, typically a Model D™ or F-1™ retainer
production packer, on wireline or tubing below the lowermost zone.
The lower zone is perforated with Tubing-Conveyed Perforating
guns. After killing the well and removing the guns from the hole, the
lower zone gravel pack assembly is run into the well below a Model
SC-type packer. The assembly is located in the sump packer with an
S-22™ snap-latch seal assembly or S-22 multiple acting indicator seal
assembly. These seal assemblies provide positive indications that
the gravel pack hookup is properly located and sealed in the sump
packer. The packer is set and the service tools released. The zone
can then be gravel packed or frac packed as required for optimized
productivity. The excess gravel slurry is reversed out of the hole and
the service tools removed from the well.
The next step in the procedure is to run a Model SB™ packer plug
or Model SB packer plug with surge chamber. The packer plug can
be run in a separate trip or on the bottom of the Tubing-Conveyed
Perforating guns for the upper zone. The plug is latched into the
packer to isolate the lower zone. A small amount of gravel pack sand
is typically dumped on top of the plug to protect it from perforating
debris. If the plug is run below the perforating guns, the guns are
picked up and located on depth and the upper zone perforated. The
well is killed and the guns are pulled from the hole. A retrieving tool
is then run to pull the packer plug. The sand and debris on the packer
plug is circulated out of the well and the retrieving tool is latched
onto the control bar of the packer plug. The plug is sheared and
allowed to equalize prior to pulling it from the packer.
The upper zone gravel pack assembly is run into the well below a
Model SC-type packer. The assembly is located in the sump packer
with an S-22B™ snap-latch seal assembly. In addition to providing a
positive indication that the gravel pack hookup is properly located
and sealed in the sump packer, the S-22B provides a polished bore
into which the washpipe of the upper zone gravel pack assembly is
sealed. By sealing the end of the washpipe in the bore of the S-22B
and installing a check valve in the washpipe, the lower zone can be
completely isolated from treating pressures (and potential fluid loss)
when gravel packing or frac packing the upper zone. After treating
the upper zone and reversing out excess slurry the service tools are
pulled from the well. At this point, additional zones can be gravel
packed or the upper completion run. The upper completion can be
configured to allow co-mingled production, a dual completion or a
selective completion as required for reservoir management.
15
Cased Hole Systems
Casing
SC Setting Tool
Top Section
Tubing Swivel Sub
SC-1 Packer
Millout Extension
Seal Bore Receptacle
Model S Gravel Pack
Extension With Sliding Sleeve
Blank Pipe
Production Screen
Model SC-1L Isolation
Packer (High Pressure)
Flush Joint Washpipe
Lower Seal Bore
(Inverted)
Model S Gravel Pack
Isolation Seal Assembly
Blank Pipe
MZ One-Trip Multi-Zone Gravel
Pack System
The MZ™ multi-zone gravel pack system is a one-trip system,
which has been optimized to provide the ability to gravel pack
or frac pack multiple intervals with a single trip into the
wellbore, while maintaining positive zonal isolation during the
treatment process.
Following the perforating of all zones, the MZ assembly is run
into the well, placed across the interval, and landed into the
sump packer. The top gravel pack packer is then set and tested
and the service tools released. The service tools are then
positioned in the bottom-most isolation packer which is set by
applying pressure, tested and then repositioned in the lower
zone circulating position where the gravel pack treatment is
carried out. This can be performed as a circulating pack, high
rate H2O-PAQ™, H2O-FRAQ™ or full hydraulic fracturing.
The crossover tool incorporates a hydraulically actuated indicator
that permits the service tool string to be positioned in critical
positions with set-down weight and allows large treatments to
be carried out without fear of the tool moving out of position due
to temperature cooling.
Once the lower zone is completed, the crossover tool is positioned in
the next zone, tested and the treatment repeated for that interval.
Production Screen
Flush Joint Pipe
Model SC-1L Isolation
Packer (High Pressure)
Mini-beta Selective
Crossover Sub
Integral Shifting Tool
Hydraulic
Actuated Indicator
Indicating Collet
Flush joint washpipe
Ported seal sub
(Inverted)
Model S Gravel Pack
Lower Seal Bore
Blank Pipe
Production screen
S-22 snap-latch
seal assembly
Model F-1
sump packer
Lower isolation
seal assembly with
check valve muleshoe
16
This process is carried out until all zones have been treated.
Cased Hole Systems
Model SC Gravel Pack System
Setting Tool/
Crossover Assembly
Bypass Port
SC-1 Packer
Gravel Pack Ports
Seal Bore Sub
Lower Extension
Indicating Ring
Knock-Out
Isolation Valve
Shear-Out
Safety Joint
Blank Pipe
™
BAKERWELD Screen
The Baker Hughes proven Model SC™ gravel pack system is the
basic platform for all cased hole gravel pack and frac pack
completions. The basic system starts with a Model D™ or F-1™
sump packer set below the interval to be treated. The gravel
pack assembly consists of an S-22™ snap-latch seal assembly,
BAKERWELD™ screen, blank pipe, Model S™ perforated gravel pack
extension and Model SC-Type packer. The service tools consist of
a Model SC setting tool, Model S2H™ crossover tool, Model S-1™
shifting tool and washpipe. For a more positive indication of the
location of the gravel pack assembly in the sump packer, the S-22
snap-latch seal assembly can be replaced with the Model S-22
multiple acting indicator seal assembly. For secondary protection
against formation sand production and erosion, the BAKERWELD
screen can be replaced with SLIM-PAK™ or EXCLUDER2000™ screen.
Incorporating a Model GPR-6™ or GPR-24™ shear-out safety joint
into the hookup above the blank pipe, facilitates retrieval of the
SC-1™ packer independently from the screen should the gravel pack
assembly need to be recovered in the future.
For enhanced post-treatment fluid loss control, a Model C™ knockout isolation valve can be placed in the hookup and the Model S™
gravel pack extension with sliding sleeve substituted for the
standard perforated extension. For higher pressure applications,
the Model SC-2™ or HP-1™ packer can be used in place of the
SC-1 packer. In frac packing applications, use of the Model CK FRAQ™
extension and CK crossover tool extend the SC gravel pack system
to the maximum rate and pressure applications. The SC gravel
pack system provides simplicity and flexibility to cover the range
of available gravel pack treatments.
Multiple Acting Indicator
Seal Assembly
Model D Sump Packer
17
Cased Hole Systems
Underbalanced TCP Assembly
The Baker Hughes retrievable packer with ported disc system is used
for perforating new wells with clear completion fluids. This system
is run with a retrievamatic packer, ported disc, and mechanical firing
head. The packer's large bypass area permits circulation around
and through the tool while running into the well. The ported disc
assembly protects the firing head from debris during makeup and
run-in and allows the tubing to fill while running into the hole. The
system can also be run with an automatic underbalancing device to
facilitate formation cleanup.
Test Head
Running In
Tubing-Conveyed Perforating (TCP) guns are run into the well with a
retrievable packer. A radioactive tag sub in the TCP string is used to
establish the gun position before perforating.
Radioactive Tag Sub
Establishing Underbalance
The desired underbalance condition is established by circulating
down the workstring with lightweight fluids. The bypass area of the
retrievamatic packer allows circulation through the tool to the ported
disc assembly located above the guns. A reduced ID “No-Go” guide
sub protects the firing head from unintentional detonation while
ensuring that the detonating bar strikes the hammer properly when
detonation is desired.
Retrievamatic Packer
Firing Guns
To fire the guns, a detonating bar is dropped from the surface,
striking the firing head and initiating detonation of the perforating
guns. Produced reservoir fluids surge against the underbalanced
tubing pressure upon perforation of the casing and the formation.
Tubing Spacers
Ported Disc Assembly
Stabilizing the Well
After flow tests are completed, the well is stabilized by opening
the bypass on the retrievable packer. This position allows reverse
circulation of debris and reservoir fluids to the surface, replacing
them with heavier weight fluids.
Pup Joints
Mechanical Firing Head
Perforating Gun
Running in
18
Cased Hole Systems
Underbalanced TCP Assembly
Reverse Circulation
Through Packer
Detonating Bar
Mechanical
Firing Head
Perforating Guns
Underbalance
Guns firing
Stabilizing the well
19
Cased Hole Systems
Oriented Perforating for Sand Prevention
The Baker Hughes Tubing-Conveyed Perforating (TCP) system in
deviated wellbores is ideally suited for low-side or directional
perforating. The combination of a tubing swivel and orienting lugs
ensures the proper orientation of the gun system. Low side capability
permits perforating of long horizontal sections that have excessive
leak-off during gravel pack operations.
Running In
The orienting lugs and tubing swivel facilitate gun orientation to
the low side of the hole as the TCP workstring is run into the hole.
Tubing
Firing Guns
Nitrogen or a lightweight completion fluid is circulated into the
hole to establish the desired underbalance. Tubing pressure is then
applied and bled off to activate the firing heads, detonating the
perforating guns.
Ported Sub
Well Flowing
The well is flowed through the ported sub and up the tubing.
Production is then monitored at the surface.
Tubing Swivel
Stabilizing the Well
The packer bypass is opened to allow reverse circulation through
the bypass and flow ports to stabilize the well.
Model D Firing Head
Model RD Adapter
Orienting Lugs
Perforating Gun
Running in
20
Cased Hole Systems
Oriented Perforating for Sand Prevention
Guns firing
Well flowing
Stabilizing the well
21
Non-Conventional Systems
Prepacking With Perforating Gun Assembly
Prepacking a cased-hole perforated interval provides many benefits
to the overall success of a high rate annular gravel pack. Upon
firing the TCP guns, the well is reversed out as normal in order to
stabilize fluid conditions. Once the well is stable, the retrievable
packer can then be unset and the end of the BHA can be positioned
approximately 100 ft (30 m) above the top shot. At this position,
the retrievable packer can be reset and an H2O-PAQ™ or H2O-FRAQ™
treatment can be performed.
Benefits of Prepacking With Perforating Guns in Hole
 Eliminates
possible need for placing fluid loss control material
into empty perforations
 If fluid loss control material is needed, it can be placed inside
casing, allowing easier cleanup
 Provides good leakoff leading to improved perforation packing
 Creates clean perforation tunnels
 Extra trip with packer/tailpipe assembly is eliminated
Blank Tubing
Blank Tubing
Mechanical Firing Head
Perforating Gun
Guns firing
22
Prepacking the well
Over the Top Gravel Pack Tool
Casing
Bumper Sub
The Over the Top gravel pack tool is designed to place gravel by
a crossover circulating method when running screen or liner on
a landing nipple. The lefthand square thread on the release nut
attaches to the landing nipple while the two down-facing packer
cups direct flow down the screen/casing annulus.
During gravel packing, the slurry flows out the crossover port below the
packer cups, and over the landing nipple to the screen casing annulus.
Returns are taken through the screen or slotted liner, into the tailpipe,
through the bypass ports above the cups, and up the annulus.
Bypass Ports
Upon completing the gravel packing process, excess slurry is
reversed from the workstring by pumping down the annulus over
the packer cups and into the gravel pack port. A check valve prevents
fluid from flowing into the ID of the slotted liner or screen.
Over the Top
Gravel Pack Tool
Gravel Pack Port
Landing Nipple
Check Valve
Blank Pipe
Washpipe
BAKERWELD™ Screen
Bull Plug
23
Hook-Wall Gravel Pack System
Casing
Workstring
Model C Gravel Pack
Crossover Kit
Model R-3 Packer
The Hook-Wall™ gravel pack system makes use of a Model R-3™
double-grip retrievable casing packer to replace the cup-tools used
in standard Over the Top gravel pack systems. This packer features
a large bypass flow area, which is controlled by a face seal type
valve that is activated by a 30-in. (762.0-mm) stroke mandrel. The
double-grip version of this packer features an hydraulic button-type
holddown that is located below the bypass valve, thus allowing the
packer to be used when pressure is applied from below.
The packer can be fitted with an integral crossover kit to allow
circulation. During gravel packing, slurry is pumped down the
workstring, out the crossover tool (or port collar), and over the
landing nipple to the screen casing annulus. Returns are taken
through the screen or slotted liner, into the tailpipe, through the
clutch joint assembly, through the packer bypass, and up the annulus.
Bypass Crossover
Ball Check Valve
Stuffing Box and
Clutch Joint Assembly
Landing Nipple
Blank Pipe
Washpipe
Screen
Bull Plug
Bridge Plug
24
Upon completing the gravel packing process, the workstring is raised to
open the unloader sub, and fluid is pumped down the annulus, through
the unloader sub, into the gravel pack port, and up the workstring.
With reversing complete, the workstring is raised to release the packer
and engage the clutch joint, allowing right-hand rotation to be applied
to release the stuffing box from the landing nipple.
This system can be an economic alternative to the SC™ gravel
pack system for situations where a single-position crossover tool,
limited reversing rates and lack of pressure isolation during reversing
are acceptable.
Packers
SPECIFICATION GUIDE
Models SC and HP Packers (Models SC-2, SC-2R, SC-2A, HP-1, HP-1A, SC-1, SC-1R, SC-1A, and SC-1AR Packer)
Casing
Packing Element OD
Casing ID Range
OD
(in.)
4-1/2
5
5-1/2
6
6-5/8
T&C Weight
(lb)
Min ID
Preferred
Min ID
Max
ID
11.6
3.982
3.997
4.000
9.5 - 10.5
4.035
4.050
4.090
20.8 - 21.4 4.112
4.127
Bore
Type
Size
Gauge
Ring
OD
New
SC-1
SC-1R
SC-1A
SC-1AR
SC-2
SC-2A
SC-2R
HP-1
HP-1A
3.750
3.750
Absolute
Limits of
Slip Travel
Min
Max
45A-25
3.817
45B-25
3.870
4.156
45C-25
3.947
3.827
3.827
3.823 4.236
Single
3.715 4.080
3.769 4.170
18
4.258
4.273
4.276 Single
50A-26
4.093
4.031
4.031
4.006 4.356
11.5 - 15
4.388
4.403
4.560
50B-26
4.223
4.156
4.156
4.080 4.640
20 - 23
4.665
4.725
4.778
4.485
4.406
4.406
4.374 4.858
17 - 20
4.773
4.833
4.892
4.593
4.500
4.500
4.416 5.030
13 - 15.5
4.945
5.005
5.004
4.765
4.687
4.687
4.596 5.124
23 - 26
5.000
5.125
5.295
4.945
-
4.870
4.786 5.375
32 - 35
5.535
5.595
5.720
24 - 28
5.742
5.802
5.921
32 - 38
5.915
5.975
6.105
Single 55A2-26
Dual
55A2-32
Single 55A4-26
Dual
55A4-32
Single
55B-26
Dual
55B-32
Single
55C-26
Dual
55C-32
Single
66A2-32 5.355
5.281
5.312
5.217 5.800
66A4-32 5.562
5.437
5.437
5.385 6.001
Min
Bore
Dia Seal
Thru
Bore for
Packer Seal Nipples
Body
Dual
6.000
6.060
20-25
25
3.437 OD
8 Stub Acme
2.500
2.500
20-25
1.875
20-25
25
3.437 OD
8 Stub Acme
2.688
2.688
40-26
1.968
20-26
26
3.437 OD
8 Stub Acme
2.688
40-26
1.968
40-26
2.500
40SCA-32
1.968
40-26
2.500
40SCA-32
26
4 OD
Seal-Lock HT
26
4 OD
Seal-Lock HT
32
4-1/2 OD
Seal-Lock HT
32
4-1/2 OD
Seal-Lock HT
40
5-1/2 OD
Seal-Lock HT
3.250/2.688 40SCA-32
2.688
Dual
2.688
2.688
2.688
3.250
2.688
23 - 29
7
17 - 20
6.180
6.430
6.240
6.490
Dual
70B-40
Single
70C-32
6.366
6.560
2.406, 1.990
80-32
Dual
4.000/3.250
3.250
6.059 6.618
23 - 29
17 - 20
6.000
6.180
6.430
6.060
5.820
5.750
5.750
5.688 6.264
6.000
5.937
5.937
5.842 6.446
6.250
6.187
6.187
6.100 6.618
70C-40
6.240
6.490
6.184
Dual
70A4-47
Single
70B-40
6.366
Dual
70B-47
Single
70C-40
6.560
Dual
70C-47
82SCA-40,
3.280, 3.000 80SCA-40
80SCA-40
81-32,
80-32
2.406, 1.990
80-32
82SCA-40,
3.280, 3.000 80SCA-40
80SCA-40
81-32,
80-32
2.406, 1.990
80-32
82SCA-40,
3.280, 3.000 80SCA-40
80SCA-40
81-32,
80-32
2.406, 1.990
80-32
82SCA-40,
4.000/3.250
3.280, 3.000 80SCA-40
80SCA-40
Single 70A4-40
29 - 35
40SCA-32
81-32,
80-32
5.809 6.446
6.187
2.500
3.250
3.250
6.187
40-26
80-32
4.000/3.250
6.250
1.968
2.406, 1.990
5.545 6.264
5.937
40-26
40SCA-32
81-32,
80-32
5.750
5.937
1.968
2.500
3.250
3.250
6.000
40-26
3.250/2.688 40SCA-32
3.250
70B-32
40-26
3.250/2.688 40SCA-32
70A4-40
Single
40-26
3.250/2.688 40SCA-32
4.000/3.250
5.820
Box Thread
Down (in.)
1.875
70A2-40
6.184
Expen
Plug
Size
20-25
Single 70A4-32
29 - 35
Packer
Accessory
Size
2.500
5.687
5.687
Min Bore
Thru Seal
Nipples
2.500
Single 70A2-32
5.732
Seal
Accessory
Size
4.000
82-40,
80-40
3.280, 3.000
80-40
82SCA-47,
4.750/4.000
4.032, 3.875 80SCA-47
80SCA-47
4.000
4.000
82-40,
80-40
3.280, 3.000
80-40
82SCA-47,
4.750/4.000
4.032, 3.875 80SCA-47
80SCA-47
4.000
82-40,
80-40
3.280, 3.000
80-40
82SCA-47,
4.750/4.000
4.032, 3.875 80SCA-47
80SCA-47
NOTE: In some cases, more than one size packer may be available for the same casing size and weight. The preferred minimum to the maximum casing ID range
should be the guide for proper packer selection. Contact your Baker Hughes Representative for assistance.
25
Packers
SPECIFICATION GUIDE
(Continued)
Casing
Packing Element OD
Casing ID Range
OD
(in.)
T&C Weight
(lb)
Min ID
Preferred
Min ID
Max
ID
6.620
6.680
6.765
29.7 - 33.7 6.760
33.7 - 39
6.820
6.950
24 - 29.7
6.870
6.930
7.025
20 - 26.4
6.940
7.024
7.125
33.7 - 39
6.620
6.680
6.765
29.7 - 33.7 6.760
6.820
6.950
Bore
Type
Single
New
SC-1
SC-1R
SC-1A
SC-1AR
SC-2
SC-2A
SC-2R
HP-1
HP-1A
76A2-32 6.440
6.375
6.375
76A4-32 6.580
6.500
Size
Gauge
Ring
OD
76B2-32 6.690
76B4-32 6.784
6.625
6.500
6.625
Absolute
Limits of
Slip Travel
Min
Max
Min
Bore
Dia Seal
Thru
Bore for
Packer Seal Nipples
Body
7-5/8
76A2-47
6.372 7.105
6.718
6.592 7.205
6.252 6.842
6.440
6.375
6.375
6.580
6.500
6.500
3.250
76A4-47
24 - 29.7
6.870
6.930
7.025
Dual
76B2-47
8-5/8
6.964
7024
7.125
Dual
76B4-47
44 - 49
7.490
7.550
7.680
86A2-47 7.310
7.710
7.770
7.890
86A4-47 7.530
32 - 36
7.805
7.865
7.985
24 - 32
7.900
7.960
8.097
53.5 - 58.4 8.371
6.625
6.784
36 - 40
Single
86AB-47 7.625
7.250
7.500
86B-47
7.720
7.625
6.592 7.205
-
7.380 8.275
8.431
8.561
96A-40
8.191
8.125
8.125
8.050 8.750
8.559
8.689
96A2-40 8.319
8.250
8.250
8.175 8.880
40 - 47
8.645
8.705
8.835
96A4-40 8.465
8.375
8.375
8.320 9.025
36 - 40
8.799
8.859
8.989
96B-40
8.500
8.500
8.475 9.185
Single
9-5/8 53.5 - 58.4 8.371
8.431
8.561
Dual
8.125
4.000
4.000
8.499
8.559
8.689
Dual
96A2-60
x 40
80-40
4.032, 3.875 80SCA-47
3.875, 3.000
120-47
47
6-5/8 OD
Seal-Lock HT
82-40, 80-40 3.280, 3.000
190-40
-
5-1/2 OD
Seal-Lock HT
47
6-5/8 OD
Seal-Lock HT
-
5-1/2 OD
Seal-Lock HT
47
6-5/8 OD
Seal-Lock HT
-
5-1/2 OD
Seal-Lock HT
192-47,
190-47
190SCA-60
4.875
6.000/4.000
4.750
4.750
8.250
3.875, 3.000
6.000/4.750
4.000
8.250
80-40
4.032, 3.875 80SCA-47
82-40, 80-40 3.280, 3.000
192-47,
190-47
8.050 8.750
96A-60
x 40
96A2-60
8.319
x 47
82SCA-47,
81SCA-47
4.750
4.750
8.125
5-1/2 OD
Seal-Lock HT
80-40
4.032, 3.875 80SCA-47
82-40, 80-40 3.280, 3.000
4.750
4.750
8.191
82SCA-47,
81SCA-47
4.750/4.000
Single 96A2-47
47 - 53.5
4.000
4.032, 3.875 80SCA-47
82-40, 80-40 3.280, 3.000
82SCA-47,
81SCA-47
96A-47
96A-60
x 47
40
80-40
82SCA-47,
81SCA-47
7.180 7.828
8.499
8.619
4-1/2 OD
Seal-Lock HT
82-40, 80-40 3.280, 3.000
4.000
6.718
32
4.000
4.750/4.000
47 - 53.5
Single
4.000
6.625
Single 76B4-40
20 - 26.4
Box Thread
Down (in.)
80-32
4.750/4.000
6.372 7.105
6.690
Expen
Plug
Size
81-32, 80-32 2.406, 1.990
4.000
Single 76B2-40
Packer
Accessory
Size
3.250
4.750/4.000
Single 76A4-40
Dual
Min Bore
Thru Seal
Nipples
6.252 6.845
Single 76A2-40
Dual
Seal
Accessory
Size
192-47,
190-47
3.875, 3.000
6.000/4.750
8.175 8.880
190SCA-60
4.000
6.000/4.000
4.875
190-47
190SCA-60
x 47 l
190SCA-60
x 40 l
190-47
190SCA-60
x 47 l
190SCA-60
x 40 l
l Size 190-60 Hydro-Set adapter kit.
NOTE: In some cases, more than one size packer may be available for the same casing size and weight. The preferred minimum to the maximum casing ID range
should be the guide for proper packer selection. Contact your Baker Hughes Representative for assistance.
26
Packers
SPECIFICATION GUIDE
(Continued)
Casing
Packing Element OD
Casing ID Range
OD (in.)
T&C Weight
(lb)
Min ID
Preferred
Min ID
Bore
Type
Max ID
Single
40 - 47
8.645
8.705
8.835
Dual
Single
36 - 40
8.799
8.859
8.989
Dual
9-5/8
53.5
8.461
8.521
8.651
43.5 - 47
8.620
8.680
8.810
32 - 40
8.788
8.848
58.4
8.399
53.5
8.493
47
43.5
SC-2
SC-2A
SC-2R
HP-1
HP-1A
96A4-60
x 47
8.465
8.375
8.375
4.750
8.619
8.500
8.500
96B-60
8.608
8.459
8.589
96A-60
8.219
8.119
8.553
8.683
96B-60
8.313
8.213
8.632
8.692
8.822
96B2-60
8.452
8.702
8.762
8.892
96C-60
8.522
8.125
8.375
-
-
8.532
8.778
8.838
8.968
96C2-60
8.589
8.498
8.860
8.920
9.505
96C4-60
8.680
8.580
55.5 - 60.7
9.580
9.640
9.770
65 - 71
9.870
10.550
9.930
10.610
10.050
10.730
8.475
Dual
107B2-75
Single
117A-60
Dual
117A-75
3.875, 3.000
190-47
9.400
192-47,
190-47
10.370
8.769
8.342
9.018
8.480
9.249
8.100
8.610
8.190
8.840
8.400
-
4.875
Box Thread
Down (in.)
47
6-5/8 OD
Seal-Lock HT
-
5-1/2 OD
Seal-Lock HT
47
6-5/8 OD
Seal-Lock HT
190SCA-60
x 40 l
-
5-1/2 OD
Seal-Lock HT
190SCA-60
x 47 l
190SCA-60
x 40 l
190-47
190SCA-60
x 47 l
6.000/4.000
6.000
6.000
190-60
4.875
190-60
60
7-5/8 Boss
6.000
6.000
190-60
4.875
198-60
60
7-5/8 Boss
6.000
190-60
4.875
210-60
7.500/6.000
190SCA-75
6.031
210SA-75
6.000
190-60
4.875
210-60
60
7-5/8 Boss
7.500/6.000
190SCA-75
6.031
210SA-75
6.000
190-60
4.875
210-60
7.500/6.000
190SCA-75
6.031
210SA-75
60
7-5/8 Boss
9.070
9.720 10.130
6.000
9.560
10.250
3.875, 3.000
Expen
Plug
Size
4.000
9.340
Special
Order
9.690
8.168
4.875
6.000/4.750
9.185
8.422
40
107A4-75
192-47,
190-47
190SCA-60
8.978
Single 107B2-60
Packer
Accessory
Size
6.000/4.000
4.750
96B-60
x 40
Single 107A4-60
Min Bore
Thru Seal
Nipples
190SCA-60
96B-47
96B-60
x 47
Seal
Accessory
Size
6.000/4.750
9.025
4.000
36
40.5 - 45
8.320
96A4-60
x 40
8.440
Dual
Max
4.750
8.281
Single
Min
Min
Bore
Dia Seal
Thru
Bore for
Packer Seal Nipples
Body
4.750
96A4-60
Single
Absolute
Limits of
Slip Travel
96A4-47
96A2-60
10-3/4
11-3/4
Size
Gauge
Ring
OD
New
SC-1
SC-1R
SC-1A
SC-1AR
9.949 10.980
6.000
l Size 190-60 Hydro-Set adapter kit.
NOTE: In some cases, more than one size packer may be available for the same casing size and weight. The preferred minimum to the maximum casing ID range should
be the guide for proper packer selection. Contact your Baker Hughes Representative for assistance.
27
Packers
SPECIFICATION GUIDE
Models SC and HP Packers
Model Size
Dual Bore Packers
Model and Product Family Number
New SC-1
(H48820)
SC-2
(H48807)
HP-1
(H48816)
45A-25



N/A
New SC-1R
(H48861)
SC-2R
(H48863)
New SC-1A
(H48822)
SC-2A
(H48815)
HP-1A
(H48818)
45B-25



N/A
45C-25



N/A
50A-26



N/A
50B-26



N/A
55A2-26





N/A
55A4-26





N/A
55B-26





N/A
55C-26
New SC-1AR
(H48865)
N/A

55A2-32 x 26
N/A


55A4-32 x 26
N/A


55B-32 x 26
N/A


N/A

55C-32 x 26

66A2-32



N/A
66A4-32



N/A
70A2-32





N/A
70A4-32





N/A
70B-32





N/A
70C-32





N/A
70A2-40 x 32
N/A


70A4-40 x 32
N/A


70B-40 x 32
N/A


70C-40 x 32
N/A


70A4-40


N/P


N/A
70B-40


N/P


N/A
70C-40


N/P


N/A
70A4-47 x 40
N/A

N/P
70B-47 x 40
N/A

N/P
70C-47 x 40
N/A

N/P
76A2-32




N/A
76A4-32




N/A
76B2-32




N/A
76B4-32




N/A
76A2-40





N/A
76A4-40





N/A
76B2-40





N/A
76B4-40





N/A
76A2-47 x 40
N/A

76A4-47 x 40
N/A

76B2-47 x 40
N/A

N/A - Not Applicable
N/P - Not Possible
28
Single Bore
Packers
SPECIFICATION GUIDE
Models SC and HP Packers (Continued)
Model Size
New SC-1
(H48820)
Single Bore
Dual Bore Packers
SC-2
(H48807)
HP-1
(H48816)
76B4-47 x 40
New SC-1R
(H48861)
SC-2R
(H48863)
N/A
New SC-1A
(H48822)
SC-2A
(H48815)
HP-1A
(H48818)
New SC-1AR
(H48865)

86A2-47

N/A
86A4-47

N/A
86AB-47

N/A
86B-47

N/A
96A-40



N/A
96A2-40



N/A
96A4-40



N/A
96B-40



N/A
96A-47


N/P

N/A
96A2-47


N/P

N/A
96A4-47


N/P

N/A
96B-47


N/P

N/A
96A-60 x 40
N/A
N/P

96A2-60 x 40
N/A
N/P

96A4-60 x 40
N/A
N/P

96B-60 x 40
N/A
N/P
96A-60 x 47
N/A

N/P

96A2-60 x 47
N/A

N/P

96A4-60 x 47
N/A

N/P

96B-60 x 47
N/A

N/P

96A2-60
N/P

N/P
N/A
96A4-60
N/P

N/P
N/A

N/P
N/A
96A-60

N/P

N/A
96B-60
96B-60
N/P

N/P

N/A
96B2-60

N/P

N/A
96C-60

N/P

N/A
96C2-60

N/P

N/A
96C4-60

N/P

N/A
107A4-60


107B2-60


N/A
N/A
107A4-75 x 60
N/A

107B2-75 x 60
N/A

117A-60
117A-75 x 60



N/A

N/A

N/A - Not Applicable
N/P - Not Possible
29
Packers
Model SC-1 Gravel Pack Packer
Product Family No. H48820
APPLICATION
The Model SC-1™ gravel pack packers are fully retrievable, high performance gravel pack or
production packers. Except for the packing element system and gauge rings, all parts are
interchangeable with the corresponding size and style of the SC-2™ packers. The SC-1 packer and
the SC-2 packer use the same packer size designations for any given casing size and weight range.
Although it was primarily designed for use in gravel pack applications, it may also be used as a
completion packer where a high performance retrievable retainer production packer is required.
The Model SC-1 gravel pack packer is fully compatible with standard Baker Hughes sealing
accessories, including retrievable and/or expendable plugs.
The Model SC-1 gravel pack packer is capable of withstanding differential pressures up to 6,000 psi
(41.1 MPa) max (depending on size) at temperatures up to 250°F (120°C) from above or below.
Features/Benefits
 Short
overall length; only slightly longer than the comparable size permanent production
packer, facilitating easier running/retrieving through “doglegs” and tight spots
 Single, self-energizing “cup forming” packing element for repeated low and high
differential pressure reversals
 Cast iron components of the exterior components above the slips to enhance the
emergency milling up of the packer should it be impossible to retrieve by the conventional
method (i.e., a straight pull)
 A hydraulically operated interlocking device, incorporated into the setting sleeve,
preventing the pre-setting of the packer during run-in
Setting: The Model SC-1 packer can be set using a hydraulic setting tool in combination with a
crossover tool or a hydro-set adapter kit. For some sizes, it can also be set using a wireline adapter kit.
Retrieval: The Model SC-1 packer is released and retrieved with a Model S-1 retrieving tool
using simple straight pull.
Optional Features
SC-1A™ (Product Family No. H48822): Features a larger sealing bore in the upper end, permitting
the use of larger through-bore packer accessories.
SC-1R™ (Product Family No. H48861): Features a rotationally locked setting mechanism that allows
the packer and the entire gravel pack assembly to be rotated and reciprocated, when necessary, while
running in the hole.
SC-1AR™ (Product Family No. H48865): Combines a larger upper bore with a rotational lock
Note: Not all optional features are available in all sizes, see Packer Availability Chart.
30
Model SC-1 Gravel Pack Packer
Packers
Model SC-1L Isolation Packer
APPLICATION
The Model SC-1L™ isolation packer was developed for isolating zones in multi-zone gravel pack
operations. Setting force is provided by applied tubing pressure which acts on a piston area in the top
of the packer. The tool is supplied either with an SC-1™ Type packing element or a Model F™ packing
element system and has no slips. The assembly must therefore be held in position, (e.g., by being
attached to a standard packer either above or below). Centralizers should be run above and/or below the
isolation packer so that it won't set too far “off center” in the casing. Packoff force is retained by a body
lock ring. Depending on the application, these packers can be supplied with or without a honed ID.
Tubing pressure shears the screws in the top sub to begin the setting motion. To fully packoff the
packing element, tubing pressure should then be increased to the minimum value shown in the
setting information table, held for 3 minutes, and bled to zero. Repeat this pressure cycle.
No means are provided for relieving the force stored in the body lock ring. For this reason, the
packing element stays energized.
SPECIFICATION GUIDE
Weight
Range
Casing
in.
mm
7
177.8
7-5/8
9-5/8
Packer
Size
Max OD
lb/ft
in.
mm
in.
mm
32 - 35
5.992 - 6.094
152.2 - 154.8
70A-36
5.812
147.6
29
6.148 - 6.184
156.2 - 157.1
70B2-36
5.968
151.6
32 - 35
5.992 - 6.094
152.2 - 154.8
70A-40
5.812
147.6
26 - 32
6.039 - 6.279
153.4 - 159.4
70A6-40 
5.859
148.8
29
6.148 - 6.184
156.2 - 157.1
70B2-40
5.968
151.6
23 - 26
6.258 - 6.366
159.0 - 161.7
70B4-40
6.078
154.4
20 - 23
29.7 - 33.7
58.4
47 - 53.5
6.180 - 6.456
6.765 - 6.875
6.852 - 6.969
6.680 - 6.875
8.435 - 8.560
8.499 - 8.681
157.0 - 164.0
171.8 - 174.6
174.0 - 177.0
169.7 - 174.6
214.2 - 217.4
215.9 - 220.5
70B6-40 
76A4-36
76B2-36
76B-38 
96A2-60
96A3-60 
6.000
6.593
6.672
6.500
8.281
8.319
152.4
167.5
169.5
165.1
210.3
211.3
47
8.620 - 8.681
219.0 - 220.5
96A4-60
8.440
214.4
43.5 - 47
40
36 - 40
8.602 - 8.755
8.788 - 8.835
8.788 - 8.921
218.5 - 222.4
223.2 - 224.4
223.2 - 226.6
96A4-60 
96B-60
96B-60 
193.7
244.5
ID Range
8.422
213.9
8.608
218.6
Min ID
Honed ID
in.
mm
in.
mm
3.625
92.1
3.625
92.1
4.000 •
101.6 •
4.000
101.6
3.975 •
101.0 •
None
None
4.000 •
4.000 •
3.975 •
4.000 •
101.6 •
101.6 •
101.0 •
101.6 •
4.000
4.000
None
4.000
101.6
101.6
None
101.6
3.975 •
101.0 •
None
None
4.000 •
101.6 •
4.000
101.6
3.625
92.1
3.625
92.1
3.865
98.2
None
None


6.000
152.4


5.906
150.0
6.000
None
152.4
None


6.000
152.4
 Uses
F-1™ packing element system
Values shown are for packers with standard 4-1/2 in. (114.3 mm) or 5 in. (127.0 mm) casing threads in the bottom sub. Smaller
threads may result in a restriction through the bottom sub.
 Minimum ID through these packers is governed by bottom sub ID
•
Model SC-1L Isolation Packer
SC-1L ISOLATION PACKER SETTING INFORMATION
Size
70-36
70-40
70-40 
76-36
76-38 
90-60
96-60 
 Uses
Piston Area
Tripping Pressure
Min Setting Pressure
Equivalent Min Setting Force
Sq in.
cm2
psi
mPa
psi
mPa
lb
kg
10.806
10.806
9.550
10.806
12.070
11.047
69.72
69.72
61.61
69.72
77.87
71.27
2,640
2,640
2,000
2,640
2,370
1,500
18.2
18.2
13.8
18.2
16.3
10.3
3,000
3,000
2,500
3,000
3,000
2,500
20.7
20.7
17.2
20.7
20.7
17.2
32,400
32,400
23,900
32,400
36,200
27,600
14,696
14,696
10,841
14,696
16,420
12,519
11.047
71.27
1,500
10.3
2,500
17.2
27,600
12,519
F-1™ Packing element system
31
Packers
Model SC-1 Thermal Gravel Pack Packer
APPLICATION
The Model SC-1™ thermal packer is a standard SC-1 packer
equipped with a packing element system that enables it to be
used for both gravel packing and steam injection. The packer is
available in a size 70-40 for application in 7 in. (177.8 mm) casing.
Features/Benefits
 Maximum
recommended temperature 580°F (304°C)
at 2,000 psi (13.8 MPa)
 Capable of withstanding pressure differentials up to
3,000 psi (20.7 MPa) from above and below during
gravel packing
 Supports up to 150,000 lb (68,000 kg) of tailpipe weight
Model SC-1R Thermal Gravel Pack Packer
APPLICATION
The SC-1R™ thermal GP packer is a standard SC-1R packer equipped
with a thermal packing element system that enables it to be used
for both gravel packing and steam injection. The packer is available
in a size 96-60 for application in 9-5/8 in. (244.5 mm) casing.
Features/Benefits
 Maximum
recommended temperature is 580°F (304°C)
at 2,000 psi (13.8 MPa). Minimum recommended
temperature after injection is 250°F (120°C)
 Capable of withstanding pressure differentials up to
2,000 psi (13.8 MPa) from above and belowduring initial
gravel pack operations
 Supports up to 130,000 lb (59,000 kg) of tailpipe weight
Model SC-1R Thermal
Gravel Pack Packer
Model SC-1 Thermal
Gravel Pack Packer
32
Packers
Model SC-2 Packer
APPLICATION
The Model SC-2™ gravel pack packers are fully
retrievable, high performance gravel pack or
production packers. Except for the packing element
system and gauge rings, all parts are interchangeable
with the corresponding size and style of the SC-1™
packers. The SC-1 packer and the SC-2 packer use
the same packer size designations for any given
casing size and weight range.
Although it was primarily designed for use in gravel
pack applications, it may also be used as a completion
packer where the need for a high performance
retrievable retainer production packer is required.
The Model SC-2 gravel pack packer is fully compatible
with standard Baker Hughes sealing accessories,
including retrievable and/or expendable plugs.
The Model SC-2 gravel pack packer is capable of
withstanding differential pressures up to 7,500 psi
(51.7 MPa) (depending on size) at temperatures up
to 350°F (175°C) when in production mode. The
SC-2 packer has a 10,000 psi (68.9 MPa) frac pack
service rating at 350°F (175°C).
Setting: The Model SC-2 packer can be set
using a hydraulic setting tool in combination
with a crossover tool or a hydro-set adapter
kit. For some sizes, it can also be set using a
wireline adapter kit.
Retrieval: The Model SC-2 packer is released
and retrieved with a Model S-1 retrieving tool
using simple straight pull.
Optional Features
SC-2A™ (Product Family No. H48815):
Features a larger sealing bore in the upper
end, permitting the use of larger through-bore
packer accessories.
SC-2R™ (Product Family No. H48863):
Features a rotationally locked setting mechanism
that allows the packer and the entire gravel pack
assembly to be rotated and reciprocated, when
necessary, while running in the hole.
Note: Not all optional features are available in all
sizes, see Packer Availability Chart.
Features/Benefits
 Short
overall length facilitates easy running and retrieving through “doglegs”, tight spots,
and short radius curves
 Single, self-energizing “cup forming” packing element for repeated low and high differential
pressure reversals
 Packing element is totally enclosed by chemically resistant, zero extrusion back-up system to
ensure extended downhole life
 Cast iron construction of the exterior components above the slips to enhance the emergency
milling up of the packer should it be impossible to retrieve by the conventional method
(i.e., a straight pull)
 A hydraulically operated interlocking device, incorporated into the setting sleeve, preventing
the pre-setting of the packer during run-in
 Casing range from 4-1/2-in. to 9-5/8-in. (114.3-mm to 244.4-mm), with 10-3/4-in. (273.1-mm)
available by special order
Model SC-2 Packer
33
Packers
Model HP-1 Packer
APPLICATION
The Model HP-1™ packer is a fully retrievable, high performance
retainer production packer. Although the packer was originally
designed for premium gravel pack applications, it may also be used as
a standard completion packer in high pressure and high temperature
wells where a premium retrievable production packer is required.
The component profiles of the HP-1 packer are identical to the
component profiles of the SC-2™ packer except for slight differences
in the packing element back-up rings and gauge rings. The only
other difference between the high performance SC-2 packer and
the higher performance HP-1 packer is the use of higher strength
materials for the stressed components of the HP-1 packer.
The Model HP-1 packer is fully compatible with standard
Baker Hughes sealing accessories, including retrievable and
expendable plugs.
Features/Benefits
 The packer is rated to withstand pressures from
10,000 to 12,000 psi (68.9 to 82.7 MPa) at a temperature
of 450°F (230°C).
 Short overall length facilitates easy running and
retrieving through “doglegs” and tight spots
 Single, self-energizing, “cup forming”, packing element
for repeated low and high differential pressure reversals
 Packing element totally enclosed by chemically resistant,
zero extrusion, back-up system to ensure extended
downhole life
 Hydraulically operated, mechanical interlock incorporated
into setting sleeve prevents pre-setting of the packer
during run-in
 Cast iron construction above the slips to enhance
emergency milling of the packer should it be impossible
to retrieve by conventional methods
Optional Features
HP1-A™ (Product Family No. H48818): Features a larger sealing
bore in the upper end, permitting the use of larger through-bore
packer accessories.
34
Model HP-1 Packer
Model HP-1A Packer
Packers
Model R-3 Retrievable
Casing Packer
Double-Grip Product Family No. H64201
Single-Grip Product Family No. H64101
(Not Shown)
APPLICATION
The Model R-3™ packer is a versatile production
packer intended for a broad range of production
applications. It is a compression set type packer
suitable for stimulation and treating applications
in the double grip configuration. In applications
where excessive bottomhole pressures have been
depleted, a single-grip version can be used as an
economical production packer. It is set with one
fourth turn right-hand rotation and can be released
with straight pickup.
Bypass
Valve Seal
Mandrel
Bypass
Valve Seat
Differential
Lock (Unlocked)
Spring
Button-Type
Hold-Down
Features/Benefits
 Rugged
rocker-type slip system
 Hydraulic button-type hold-down
located below bypass valve
 Unique, built-in, “differential lock”
assists in keeping bypass closed
 Effective bypass design allows
rapid pressure equalization and
resists swab-off
 Field-proven, three piece packing
element system
3-Element
Packing System
Cone
Rocket-Type
Slips
Control-Pin
Actuated
Automatic Bottom
Model R-3 Double-Grip
Retrievable Casing Packer
Running in
Producing
Model R-3 Double-Grip Packer Operation
35
Packers
Double-Grip SC-LP Compression Packer
APPLICATION
The double-grip SC-LP™ packer is a full-opening set-down packer with button type hold-down and
built-in unloader. It is used in one-trip (perforate and complete) applications where it serves first as
the perforating packer and then as the sump packer.
Features/Benefits
 Holds
pressure from above or below. Tubing surges cannot dull the pistons because
they are isolated from the tubing by a separate circulation passage that runs
completely through the packer. The passage also serves to equalize any pressure
drop from fluid flow across the pistons
 Releases easily and dependably. By simply picking up on the tubing string, pressure
across the pistons is equalized instantly via a separate circulation passage through
the packer (not through the tubing) even if the bore of the packer is completely
plugged. Once the pressure is equalized, the pistons will retract and continued
upstrain will unpack the packing elements and release the lower slips, allowing
the packer to be retrieved
 Safe face seal unloader permits circulation completely around the tool from the
bottom up. This makes it possible to circulate out materials that might otherwise
impair retrievability
Double-Grip SC-LP
Compression Packer
36
Packers
SPECIFICATION GUIDE
Slips and Button Range
Casing
OD
in.
mm
lb
4-1/2
114.3
9.5-13
5
127.0
5-1/2
Packer
Size
Weight
139.7
15-18
11.5-15
Gauge and Guide
Ring OD 
Packing
Element OD
Slips and Buttons Range
Packing Element
Spacer OD 
Preferred
Min
Absolute
Min •
Max
Max
in.
mm
in.
mm
in.
mm
in.
mm
in.
mm
in.
mm
in.
mm
43A
3.771
95.8
3.625
92.1
3.771
95.8
3.910
99.3
4.090
103.9
3.820
97.0
4.090
103.9
43B
4.125
104.8
3.938
100.0
4.125
104.8
4.250
108.0
4.408
112.0
4.126
104.8
4.409
112.0
43C
4.250
108.0
4.156
105.6
4.250
108.0
4.408
112.0
4.560
115.8
4.274
108.6
4.561
115.8
26
43C
4.250
108.0
4.156
105.6
4.250
108.0
4.408
112.0
4.560
115.8
4.274
108.6
4.561
115.8
20-23
45-A2
4.500
114.3
4.625
117.5
4.778
121.4
15.5-20 
45-A4
4.641
117.9
4.778
121.4
4.950
125.7
4.484
113.9
4.950
125.7

4.375
111.1
4.500
114.3
6-5/8
168.3
24
47-A2
5.656
143.7
5.500
139.7
5.656
143.7
5.830
148.1
5.937
150.8
5.597
142.2
6.135
155.8
7
177.8
38
47-A2
5.656
143.7
5.500
139.7
5.656
143.7
5.830
148.1
5.937
150.8
5.597
142.2
6.135
155.8
6-5/8
168.3
17-20
47-A4
5.812
147.6
5.500
139.7
5.656
143.7
5.938
150.6
6.135
155.8
5.597
142.2
6.135
155.8
32-35
47-A4
5.812
147.6
5.500
139.7
5.656
143.7
5.938
150.6
6.135
155.8
5.597
142.2
6.135
155.8
26-29
47-B2
5.968
151.6
6.136
155.8
6.276
159.4
20-26 
47-B4
6.078
154.4
6.276
159.4
6.456
164.0
5.861
148.9
6.538
166.1
17-20
47-C2
6.266
33.7-39
47-C4
24-29.7
47-D2
20-24
47-D4
7
177.8
7-5/8
9-5/8

•

193.7
244.5
5.750
146.0
5.968
151.6
159.2
6.125
155.6
6.250
158.8
6.456
164.0
6.578
167.1
6.297
159.9
6.884
174.8
6.453
163.9
6.125
155.6
6.250
158.8
6.579
167.1
6.797
172.6
6.297
159.9
6.884
174.8
6.672
169.5
6.798
172.4
7.025
178.4
6.812
173.0
7.025
178.4
7.125
181.0
6.545
166.2
7.132
181.2
8.117
206.2
8.934
226.9
8.539
216.9
9.063
230.2
47-53.5
51-A2
8.218
208.7
40-47 
51-A4
8.437
214.3
29.3-36
51-B
8.593
218.3
6.500
165.1
6.671
169.5
7.937
201.6
8.218
208.7
8.375
212.7
8.593
218.3
8.343
211.9
220.5
220.5
8.681
220.5
224.4
224.4
6.836
224.4
230.2
230.2
It may be necessary to turn OD of gauge ring, guide ring, and packing element spacers when running in Minimum ID Casing.
This dimension is only for guidance in situations where there may be restricted diameters the tool has to pass. In some sizes, the slips “bottom out” and will not set without being damaged.
This size packer may be set in this weight casing in certain circumstances such as mixed strings or unusual hole conditions. However, the other size packer listed for this weight is
recommended and should be run where possible.
37
Packers
Model D and DB Retainer Production Packer
Product Family Nos. H41505, H41525, and H41513
APPLICATION
Baker Hughes' Model D™ and DB™ retainer production packers are the most widely used, most
versatile, high performance permanent production packers available. They are frequently used as
a permanent squeeze or testing packer, or as a permanent or temporary bridge plug.
The Model DB is distinguished from the Model D by the DB's threaded (box or pin) bottom guide.
This DB guide can be specified for acceptance of a millout extension, a seal bore extension, or
virtually any component desired. Model D packers and their guides can also be ordered separately.
Applications
Production, injection and zonal isolation
packer
 Squeeze or test packer
 Permanent or temporary bridge plug

 Sump
Features/Benefits
 Proven
reliability
 Slim-line design
 Solid construction that makes possible a significant savings in rig-time by providing
a 50% faster run-in without fear of impact damage or premature setting
 Two opposed sets of full-circle, full strength slips assure that the packer will stay
where it is set
 A packing element that resists swab-off but packs off securely when the packer is set
 Unique interlocked expandable metal back-up rings contact the casing and create a
positive barrier to packing element extrusion
®
 Aflas packing element is available in select casing weight ranges
Model DB Retainer Production Packer
with Guide for Millout Extension
Aflas is a registered trademark of Asahi Glass of Japan.
38
Packers
SPECIFICATION GUIDE
Model D Retainer Production Packer
Casing
OD
in.
4-1/2

Packer 
Weight 
mm
Size 
lb/ft
Max OD
in.
mm
17.0-18.9
19-25
3.475
88.2
15.1-17.0
21-25
3.562
90.4
11.6-15.1
22-19
3.593
91.2
10.5-11.6
23-25
24-19
3.750
3.812
95.2
96.8
32-26
15-21.4
5
127.0
32-25
3.968
34-26
2.500 63.5
1.968 49.9
23-26.8
34-19
20-23
4.250
107.9
2.688 68.2
2.500 63.5
4.250
107.9 1.968 49.9
2.688 68.2
4.328
109.9
42-19
1.968 49.9
44-26
2.688 68.2
14-17
4.500
114.3
44-19
24-32
1.968 49.9
1.968 49.9
42-26
139.7
2.688 68.2
100.7 2.500 63.5
34-25
81-32
1.968 49.9
5.350
135.8
3.250 82.5
82-32
20-32
6-5/8
168.2
5.468
138.8
82-26
2.688 68.2
84-32
20
3.250 82.5
5.687
144.4
84-26
2.688 68.2
53.6057.10
60-30
4.937
125.4 3.000 76.2
38-46.4
81-32
5.350
135.8
3.250 82.5
82-32
32-42.7
7
177.8
5.468
2.688 68.2
84-32
3.250 82.5
5.687
84-26
20-29
138.8
82-26
23-32
86-32
144.4
2.688 68.2
5.875
149.2 3.250 82.5
88-32
6.187
157.1 3.250 82.5
88-26
6.187
157.1 2.688 68.2
86-32
5.875
149.2 3.250 82.5
88-32
6.187
157.1 3.250 82.5
17-20
45.3-51.2
7-5/8
193.6
33.7-39
88-26
24-33.7
92-32
6.187
6.375
Size
mm
2.688 68.2
32-19
11.5-13
5-1/2
in.
114.3
10.5-13.5
Casing
Seal Assembly 
Diameter of
Sealing Bore
157.1 2.688 68.2
161.9 3.250 82.5
Min Bore
Thru Seals ‡
in.
OD
mm
20-25
1.865 47.3
21-19
1.312 33.3
20/40-19
.984
40/80-26
1.968 49.9
41/81-26
1.750 44.4
21-19
1.312 33.3
in.
7-5/8
.984
40/80-26
1.968 49.9
41/81-26
1.750 44.4
20-25
1.865 47.3
21-19
1.312 33.3
7-3/4
.984
40/80-26
1.968 49.9
41/81-26
1.750 44.4
20-25
1.865 47.3
21-19
1.312 33.3
8-5/8
.984
40/80-26
1.968 49.9
41/81-26
1.750 44.4
21-19
1.312 33.3
24-33.7
196.9
219.0
.984
40/80-26
1.968 49.9
41/81-26
1.750 44.4
21-19
1.312 33.3
9-5/8
244.4
36-53.5
9-7/8
250.1
62.8
24.9
20/40-19
.984
60/80-32
2.406 61.1
61/81-32
1.990 50.5
92-26
6.375
mm
6.187
mm
68.2
3.250
82.5
157.1
40/80-26
Min Bore
Thru Seals ‡
in.
mm
1.968
49.9
41/81-26
1.750
44.4
60/80-32
2.406
61.1
61/81-32
1.990
50.5
40/80-26
1.968
49.9
44.4
88-26
2.688
68.2
41/81-26
1.750
3.875
98.4
120.38
2.468
62.6
4.000 101.6
80-40
2.985
75.8
3.875
126-40
128-38
128-40
7.125
180.9
7.500
190.5
194-40
8.125
206.3
98.4
120.38
2.468
62.6
4.000 101.6
80-40
2.985
75.8
192-47
3.875
98.4
4.750 120.6
190-47
3.000
76.2
4.000 101.6
194-32
3.250
194-47
4.750 120.6
190-40
8.125
206.3
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
1.990
50.5
190-47 3.000
191-47 or 2.500
192-47 3.875
76.2
4.750 120.6
3.250
80-32 or
81-32
2.406
61.1
212-47
82.5
228.6
214-47
191-47
61/81-32
3.250
9.000
82.5
4.000 101.6
194-32
212-32
10-3/4
273.0
∆
Size
126-38
60.7-79.2
24.9
in.
161.9 2.688
194-47
24.9
20/40-19
in.
46.1-48.6
24.36
24.9
20/40-19
193.6
lb/ft
36.49
24.9
20/40-19
mm
Size 
Seal Assembly 
Diameter of
Sealing Bore
Max OD
88-32
24.9
20/40-19
Packer 
Weight 
82.5
63.5
98.4
1.990
50.5
76.2
4.750 120.6
190-47 3.000
191-47 or 2.500
192-47 3.875
3.250
80-32 or
81-32
2.406
61.1
63.5
60/80-32
2.406 61.1
61-81-32
1.990 50.5
40/80-26
1.968 49.9
41/81-26
1.750 44.4
60/80-32
2.406 61.1
61/81-32
1.990 50.5
40/80-26
1.968 49.9
41/81-26
1.750 44.4
42/62-30
2.375 60.3
40/60-30
1.970 50.0
60/80-32
2.406 61.1
61/81-32
1.990 50.5
60/80-32
2.406 61.1
61/81-32
1.990 50.5
40/80-26
1.968 49.9
41/81-26
1.750 44.4
60/80-32
2.406 61.1
61/81-32
1.990 50.5
40/80-26
1.968 49.9
41/81-26
1.750 44.4
60/80-32
2.406 61.1
61/81-32
1.990 50.5
60/80-32
2.406 61.1
61/81-32
1.990 50.5
40/80-26
1.968 49.9
41/81-26
1.750 44.4
60/80-32
2.406 61.1
61/81-32
1.990 50.5
60/80-32
2.406 61.1
61/81-32
1.990 50.5
40/80-26
1.968 49.9
 Packers for Sizes 10-3/4 in. (273.0 mm) and larger casing should be run and set on a hydraulic
41/81-26
1.750 44.4
60/80-32
2.406 61.1
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.
61/81-32
1.990 50.5
32.75-60.7
9.437
239.7
214-32
11-3/4
298.4
∆
1.990
50.5
76.2
4.750 120.6
220-32
3.250
82.5
80-32 or
81-32
2.406
61.1
1.990
50.5
230-60
6.000 152.4
190-60
4.875 123.8
42-60
13-3/8
339.7
∆
48-72
98.1
190-47 3.000
191-47 or 2.500
192-47 3.875
220-47
61-72
82.5
10.437 265.1
230-47
11.562 293.6
190-47 3.000
191-47 or 2.500
192-47 3.875
76.2
2.406
61.1
1.990
50.5
4.875 123.8
230-32
3.250
82.5
240-60
6.000 152.4
190-60
240-47
4.750 120.6
190-47 3.000
191-47 or 2.500
192-47 3.875
3.250
80-32 or
81-32
240-32
98.4
4.750 120.6
80-32 or
81-32
12.000 304.8
63.5
82.5
2.406
63.5
98.4
76.2
63.5
98.4
61.1
 For information on packer or accessory sizes not found in this specification guide, refer
to Baker Hughes’ packer systems technical manual or contact your local 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 local
Baker Hughes Representative.
‡ Minimum bore applicable to standard Models G™, E™ and K™ seal assemblies only. Not applicable to Models L™, M™, and N™ seal assemblies with K-RYTE™ and R-RYTE™ Seals which may have reduced ID’s.

 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 W.L.P.S.A. must be used. In 4-1/2 in. (114.3 mm) 9.5 and
0.5 lb/ft casing, either the size 10 or 20 W.L.P.S.A. may be used.
39
Packers
Model F-1 and FB-1 Retainer Production Packer
APPLICATION
Baker Hughes' Model F-1™ and FB-1™ retainer production packers are the “big bore”
versions of the popular Model D™ retainer production packer. They combine the features
of the D with the largest bore through any drillable packer. In the FB-1 version, a millout
extension, seal bore extension or other component can be run below the packer.
Model F-1 and FB-1 packers and their guides can also be ordered separately.
Applications
 Production,
injection and zonal isolation
 Sump packer
 Squeeze or test packer
 Permanent or temporary bridge plug
Features/Benefits
 Solid,
slim-line construction and a packing element system that resists
swab-off. This provides a faster run-in time without fear of impact damage
or premature setting, yet packs off securely and permanently when the
packer is set
 Two opposed sets of full-circle, full strength slips assure that the packer
will stay where it is set
 Unique interlocked, expandable metal back-up rings contact the casing and
create a positive barrier to packing element extension
 The largest possible opening through a drillable packer
®
 Aflas packing element is available in select casing weight ranges
Model FB-1 Retainer Production Packer
with B Guide for Millout Extension
Aflas is a registered trademark of Asahi Glass of Japan.
40
Packers
SPECIFICATION GUIDE
Model F-1 and FB-1 Retainer Production Packer
Casing
OD
in.
4-1/2 
5
5-1/2
6-5/8
7
Packer 
Weight 
mm
114.3
127.0
139.7
168.2
177.8
7-5/8
193.6
7-3/4
196.9
Size ‡
lb/ft
Seal Assembly 
Max OD
Sealing Bore 
in.
mm
11.6-15.1
22-23
3.593
91.2
9.5-11.6
24-23
3.718
94.4
24.1
22-23
3.593
91.2
21.4-24.1
24-23
3.718
94.4
20-23
43-30
4.437
112.7
14-17
45-30
4.562
115.8
14
47-30
4.750
120.6
20-24
83-40
5.687
144.4
17
85-40
5.875
149.2
32-38
83-40
5.687
144.4
26-29
85-40
5.875
149.2
20-23
87-40
6.000
152.4
17-20
89-40
6.250
158.7
33.7-42.8
91-40
6.250
158.7
24-33.7
89-40 
6.500
165.1
46.1-48.6
89-40 
6.250
158.7
40-58.4
192-60
8.218
208.4
36-47
194-60
8.438
214.3
in.
2.390
Size
mm
60.7
Min Bore
Thru Seals 
in.
mm
20-23
1.703
43.2
21-23
1.807
45.9
20-23
1.703
43.2
21-23
1.807
45.9
2.390
60.7
3.000
76.2
42/62-30 or
40/60-30
2.375 or
1.970
60.3 or
50.0
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
9-5/8
244.4
9-7/8
250.1
62.8
192-60
8.218
208.4
6.000
152.4
190-60
4.875
123.8
13-3/8
339.1
61-72
240-93
11.625
295.2
9.375
238.1
240-93
7.995
203.0
 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 W.L.P.S.A. 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 W.L.P.S.A. 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 local
Baker Hughes Representative.
‡ When proposed for use in other than the casing weight range shown contact your local Baker Hughes Representative.
 The maximum OD (including tolerance) of any part run through a Baker Hughes 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 OD’s 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) seal bore diameter.
 ID listed is for commonly used G-22 or E-22 Seal Assemblies.

41
42
Model CS Openhole Gravel Pack Extension
APPLICATION
The Model CS™ openhole gravel pack extension is connected to the bottom sub of the SC™
packer in the CS-300™ system. When used with the CS gravel pack crossover tool for gravel
packing openhole wells, the CS extension directs and controls fluid flow through the system.
The CS gravel pack extension incorporates a sliding sleeve above the lower seal bore sub.
The housing of the sleeve contains specially designed gravel exit ports.
Gravel Pack Port
The closing sleeve within the extension requires no rotation to close the sleeve. The sleeve
uses a positive engagement collet, which through the use of the Model S-1™ shifting tool
opens and closes the sleeve with only vertical movement. The sleeve is closed after gravel
packing is complete and the crossover tool is removed from the gravel pack assembly.
Closing Sleeve
The extension also incorporates the required indicating couplings that are spaced-out to
positively locate all critical positions of the crossover tool. These positions are located by
the use of the Model A SMART Collet™, with positive set-down weight. The use of indicating
positions also allows the CS-300™ system to be used with dynamically positioned rigs.
Lower Seal Bore
Indicating Couplings
Model CS Open Hole
Gravel Pack Extension
43
Model CK FRAQ Extension
Blast Liner
APPLICATION
The Model CK FRAQ™ extension is connected to the bottom sub of the packer in the CK FRAQ
system. When used in conjunction with the Model CK™ crossover tool, the CK FRAQ extension
directs and controls the fluid flow path through the system. The extension component lengths
are closely controlled to ensure proper crossover tool positioning and travel.
FRAQ Sleeve
The CK FRAQ extension consists of a housing, seal bore sub, lower extension, upper
indicating coupling, spacer extension, indicating coupling, and indicating extension.
The housing contains the proppant exit slots and blast liner designed to enhance wear
resistance and casing protection.
The indicating couplings are utilized in conjunction with the indicating collets in the service
tool string to indicate and maintain the treating positions of the crossover tool. Upon
completion of treating operations, the detent sleeve in the housing is closed when the
service tool string is pulled from the assembly.
Seal Bore Sub
Results of Independent Testing To Evaluate Wear Resistance of Available
Frac Pack Crossover Tools
Lower extension
Test Conditions:
Pump Rate: 15 bpm (2.4 m 3/min)
Fluid: Crosslinked borate gel
Casing Size: 5 in. (127 mm),
18 lb/ft (26.78 kg/m) (P-110 Grade)
Proppant: 20/40 Econoprop
Proppant Concentration: 10 ppa
Upper Indicating
Couplings
Assembly: Simulation of a 5 in. (127 mm) packer with frac pack extension,
service tools, blank pipe and screen.
Spacer Extension
Pumping Company: Third party
Testing Facility: Third party
Indicating Couplings
450,000
400,000
228,000
213,000
150,000
Indicating Extension
100,000
50,000
0
Baker Hughes
A
B
Company
44
C
77,000
200,000
Casing Failure
125,000
110,000
250,000
Tool Failure
125,000
300,000
No Tool Failure
435,000
Proppant Pumped (lbs)
350,000
D
Model CK FRAQ Extension
Model S Perforated Gravel Pack Extension
APPLICATION
The Model S™ perforated gravel pack extension is connected to the bottom sub
of the packer in the Model SC™ gravel pack system. When used in conjunction
with an SC-type or BSC-type crossover tool, the perforated extension directs and
controls the fluid flow path in the SC gravel pack system. The Model S perforated
gravel pack extension consists of a perforated extension, with gravel packing
ports, a seal bore sub, and a lower extension. The extension component lengths
are closely controlled to ensure proper crossover tool positioning and travel.
Model S Gravel Pack Extension with Sliding Sleeve
APPLICATION
This gravel pack extension incorporates a gravel pack sliding sleeve above the
seal bore sub. The housing of the sliding sleeve contains the gravel packing ports.
The lower extension is furnished long enough to allow spacing the Model S-1™
shifting tool 4 ft (1.22 m) below the lower end of the crossover tool in order to
ensure proper shifting when an indicator ring is used on the crossover tool. If no
indicator ring is used, the shifting tool may be connected directly to the crossover
tool, and the lower extension shortened accordingly. The housing of the gravel
pack sliding sleeve is made up on the upper extension, which connects to the
bottom of the packer.
When the crossover tool is pulled after completion of the gravel pack, the
shifting tool closes the sliding sleeve as it is pulled through. The gravel pack
sliding sleeve may be opened again by running the shifting tool down through it.
Features/Benefits
 Complete
operational flexibility for gravel packing. Capable of
multiple circulation modes, reverse circulation, and squeeze modes,
with the ability to use each mode whenever desired, as many times
as desired. Uses only workstring reciprocation for mode changes
 Extremely high reliability. The system is designed to work with
high-pressure integrity in a sand-laden environment
 The gravel pack extension with sliding sleeve provides a gravel
packing port that can be closed after completion of the gravel pack
and opened again whenever necessary. It also eliminates the need
of straddling off a perforated casing nipple between the packer and
the seal bore sub with long seal assemblies and is essential on dual
completions for the upper zone
Model S Perforated
Gravel Pack Extension
Model S Gravel Pack
Extension with Sliding Sleeve
45
46
Fluid Loss
Control Devices
Model C Knock-Out Isolation Valve
APPLICATION
The Model C™ knock-out isolation valve is a single-acting inverted flapper valve designed to
protect the formation from well hydrostatic pressure and resulting fluid loss after screen liner
placement or gravel packing. The valve is run between the packer and screen and contains
a frangible flapper that is held in the open position by the washpipe during run-in, screen
placement and gravel packing. As the service tools and washpipe are pulled from the well,
the flapper swings to the closed position to isolate the formation. The washpipe should be
pulled slowly in one continuous motion until the end of the washpipe is well above the valve.
Any downward motion as the end of the washpipe is coming through the valve can damage
the flapper and its seat.
For well completion, the flapper can be left intact or can be broken to open the valve. The
optimum method to open the Model C knock-out isolation valve is to pressure up within
100 psi (6.9 bar) of the total differential pressure (hydrostatic plus applied minus formation
pressure) rating and jar down with a mechanical device (wireline sinker bar assembly,
production tube or coiled tubing) to break the flapper. The valve can also be opened hydraulically
by pressuring up above the valve in excess of its differential pressure rating. Alternatively, the
valve can be opened with mechanical action alone by jarring down or spudding with a wireline
sinker bar assembly, production tube or coiled tubing to break the flapper.
Features/Benefits
 Prevents
fluid loss following gravel packing or screen placement
ID to accommodate large washpipe for gravel packing and through-bore
for completion
 Optimized OD to facilitate high rate gravel packing or frac packing
 Durable flapper withstands washpipe abrasion and closing force, but shatters
into small pieces when broken
 Frangible flapper may be broken hydraulically and/or mechanically for completion
 Large
SPECIFICATION GUIDE
Size
Max OD
Min ID
Length
Connections
Max Washpipe OD
in.
in.
mm
in.
mm
in.
mm
in.
mm
in.
mm
4
5
7
7-5/8
4.480
5.630
7.650
8.700
113.8
143.0
194.3
220.9
3.000
3.500
5.000
6.000
76.2
88.9
127.0
152.4
20.37
23.25
31.25
32.50
51.7
59.1
79.6
82.5
4
5
7
7-5/8
101.6
127.0
177.8
193.7
2.950
3.495
4.950
5.950
74.9
88.8
125.7
151.1
47
Fluid Loss
Control Devices
Isolation Tool and Retrieving Tool
Product Family No. H48735SP, and H48853SP
APPLICATION
The isolation tool is a single-acting device designed to protect and support the
flapper of the Model C™ knock-out isolation valve. While running in and during
subsequent gravel packing or treating operations, the isolation sleeve extends
completely past the flapper in the knock-out isolation valve, holding it open and
providing positive protection from damage. This device can also be used with
stacked KOIV’s to allow fluid loss control after gravel packing and after subsequent
well work such as acidizing. When desired, the isolation sleeve can be shifted
upwards and retrieved, allowing the flapper to close.
Isolation Tool
The retrieving tool can be run below the knock-out isolation valve on the washpipe,
if it is desired to close the flapper on the same run. The retrieving tool can also be
run on a separate trip to retrieve the isolation sleeve. The retrieving tool can pass
downward through the isolation sleeve and engage the lower end.
Upstrain of 15-20,000 lb (6,804-9,072 kg) will shear the screws in the isolation
sleeve and move it upward, allowing the flapper to close. In an emergency, upstrain
of 40-50,000 lb (18,144-22,680 kg) will shear the screws in the safety sub, allowing
the catch sleeve to collapse and release from the isolation sleeve.
Model C
Knock-Out
Isolation Valve
Retrieving Tool
Product Family
No. H48853SP
Features/Benefits
 Attaches
directly to the Model C knock-out isolation valve
locks in position to prevent premature release when
proper size flush joint washpipe is run
 Adjustable release force
 Accepts optimum washpipe diameter
 Positively
Isolation Tool
Product Family No. H48735SP
48
Fluid Loss
Control Devices
Fluid Loss Control Valve (FLCV)
APPLICATION
The fluid loss control valve provides a temporary barrier to control the loss of completion fluid to
the formation. Although designed and intended for use in post-gravel pack or screen placement
applications, the fluid loss control valve can also be used to facilitate setting a completion
packer or testing production tubing. The fluid loss control valve is typically run in the hole in the
open position. In this position, a flapper is held open by a sleeve. To close the flapper a shifting
tool is pulled through the valve to shift the sleeve upward.
Shifting the sleeve allows the flapper to swing closed to isolate the formation. To cycle the
flapper open, pressure is applied from above to release a flow tube which is pushed upward by
a power spring. The flow tube opens and then isolates the flapper to create a clean through-bore
for future remedial operations. The fluid loss control valve is a single-acting device and cannot
be reused after cycling open.
Features/Benefits
 Single-acting
flapper type fluid loss control valve
open, mechanically closed and hydraulically reopened
 Robust flapper based on subsurface safety valve technology
 Flapper incorporates equalizing feature to aid in opening
 Flapper incorporates rupture disc to provide hydraulic bypass in the event the
flapper does not open
 Variable opening pressure as required by well conditions
 Run-in
SPECIFICATION GUIDE
Fluid Loss Control Valve (FLCV)
Size
Max OD
Min 0D
Length
in.
in.
mm
in.
mm
in.
mm
5 x 3.31
7 x 4.56
5.810
7.700
147.57
195.58
3.315
4.565
84.20
115.95
84.00
115.95
2.134
2.183
Fluid Loss Control Valve
49
Fluid Loss
Control Devices
SAF-1 Valve
APPLICATION
The SAF-1™ valve is a reservoir isolation device in the downhole sand control assembly
that eliminates fluid loss during installation of the upper completion and facilitates the
displacement of well fluids above the valve.
Production from the isolated zone is initiated when the valve is remotely actuated to a
locked-open position by applied hydraulic pressure. In a single-string completion, pressure
can be applied to either the tubing or annulus to actuate the valve. In a dual string
completion application, actuation pressure can be applied to either the long string or short
string. The valve may also be mechanically opened with a standard B™ type shifting tool.
The SAF-1 valve is typically installed in the top zone of a multi-zone completion.
Features/Benefits
 Bi-directional
seal provides reservoir isolation and facilitates displacement of
expensive brines above the valve
 ID compatible with standard API production tubing
 Optimized concentric flow areas
 Remotely actuated with applied hydraulic pressure
 Can be mechanically opened using a B Type shifting tool
 More debris tolerant than flapper and ball valves
 Permanently locks open
 Available with 13 KSI (89.6 MPa) collapse rating
Closed Position
Open Position
SPECIFICATION GUIDE
SAF-1 Valve
Size
Tool Size
in.
in.
in.
OD
mm
in.
ID
mm
in.2
Annular Bypass
mm2
7.000
9.625
5 x 5 x 2-7/8
6-5/8 x 6-5/8 x 3-1/2
5.560
7.390
141.2
187.7
2.312
2.560
58.7
65.0
3.40
7.06
2194
4555
SAF-1 Valve
50
Fluid Loss
Control Devices
BAKERWELD Select-A-Flow II Screen
APPLICATION
BAKERWELD™ Select-A-Flow™ II offers a unique method of screen isolation for various
applications. It is constructed using a BAKERWELD screen jacket, base pipe, and a
Baker Hughes high performance nonelastomeric SLCM™ isolation valve. Opening or closing
the SLCM valve controls flow through the individual screen joints thereby providing effective
zonal selectivity when used in conjunction with gravel packing. Further isolation may be
achieved by using packers between gravel packed zones. To control fluid loss after a gravel
pack, the SLCM isolation valve may be closed by incorporating a shifting tool at the bottom of
the washpipe and shifting the valve closed when pulling the washpipe out of the screen.
BAKERWELD Select-A-Flow II's construction allows for quick and easy makeup on the rig floor.
This yields many of the benefits of an inner string without the reduction in ID by eliminating
the need to run a concentric string or a separate isolation string.
Features/Benefits
 Utilizes
the field-proven screen technology of BAKERWELD screen
nonelastomeric sliding sleeve allow for maximum ID
 Provides a method for easy production control by shifting the built-in valve
open or closed
 Eliminates the need for an isolation tubing string in many gravel pack
completion configurations
 Provides positive fluid loss control after gravel pack or stimulation operations
 Slim
SPECIFICATION GUIDE
BAKERWELD Select-A-Flow II Screen
Size
Screen OD
SLCM ID
Screen ID
Base Pipe OD
in.
in.
mm
in.
mm
in.
mm
in.
mm
2.376 x 2.695
2.375 x 2.875
2.875 x 3.500
3.500 x 4.000
3.500 x 4.500
3.16
3.45
4.08
4.58
5.09
80.3
87.6
103.6
116.3
129.2
1.875
1.875
2.313
2.313
2.813
47.6
47.6
58.7
58.7
71.4
1.947
2.000
2.441
2.995
2.995
49.5
80.8
62.0
76.0
76.0
2.695
2.875
3.500
4.000
4.500
68.5
73.0
88.9
101.6
114.3
Select-A-Flow II also available with EXCLUDER2000 filtration cartridges.
BAKERWELD
Select-A-Flow II Screen
51
Fluid Loss
Control Devices
Model RB Isolation Valve
APPLICATION
The Model RB™ isolation valve is a remotely actuated ball-type reservoir isolation valve that
provides a mechanical bi-directional downhole pressure barrier. The valve facilitates fluid loss
control, temporary well suspension, as well as safe tool deployment and upper completion
installation. The tool is designed to be compatible with sand control applications.
The RB valve is typically installed in the sand control completion assembly between the sand
screen and packer. The valve can be run into the well in either the open or closed position. If
run in the open position, the valve is mechanically closed with the Model RB closing tool when
the service tool string is removed from the valve. The valve can be cycled open by alternately
applying and releasing tubing pressure. The valve will remain closed for the first eleven
pressure cycles. On the twelfth cycle, the valve will open when the tubing pressure is bled off.
The valve can be re-closed and cycled open multiple times.
A secondary opening method utilizes the coiled tubing deployed Model RB opening tool. The
opening tool can be configured to either mechanically cycle the valve open or permanently
lock the valve open. Applied coiled tubing pressure to the opening tool actuates a secondary
opening mechanism that moves the ball valve to a permanently locked-open position
regardless of the position of the ball valve (fully closed or partially open).
Indexing Sleeve
Mechanical
Closing Tool Keys
Features/Benefits
 Isolates
formation immediately after sandface completion operation
• Reduces formation damage potential due to fluid loss
• Faster formation clean-up time reduces rig-time and costs
• Improves well control and reduces risk
 Provides bi-directional mechanical pressure barrier in the sandface
completion assembly
• Provides one of the pressure barriers for well suspension eliminating
the need for a second deep-set retrievable bridge plug
• Reduces operational steps, equipment rental, and rig-time
 Incorporates field-proven technologies from Baker Hughes safety valves and
well test tools
Lock-open
Feature
Bi-directional
Ball Valve
Model RB Isolation Valve
52
Anti-Hydraulic Lock Seal Bore
APPLICATION
The anti-hydraulic lock seal bore is used in conjunction with the Model GPV™ set shoe (Product
Family No. H48736) to provide a pump-through feature in stand-alone screen placement and gravel
pack completions. The anti-hydraulic lock seal bore is spaced-out above the Model GPV set shoe and
contains a polished bore. Seals on the end of the washpipe land in the polished bore which facilitates
circulation out the end of the screen/liner assembly (through the Model GPV set shoe) while running
in the hole. When the screen/liner is on-depth, a setting ball is typically dropped to set a packer. This
setting ball effectively blocks the flow path down the washpipe and creates a hydraulic lock against the
Model GPV set shoe when attempting to pull the washpipe upward. The anti-hydraulic lock seal bore
incorporates a check valve mechanism that relieves the hydraulic lock by allowing fluid to enter in from
above, which allows the washpipe to be moved freely upward.
Features/Benefits
 Used
in conjunction with the Model GPV set shoe
bore provides a seal point for washpipe to facilitate pump-through capability in
screen/liner assemblies
 Relieves the hydraulic lock associated with pulling the washpipe seals free after setting
the packer
 Polished
SPECIFICATION GUIDE
Size ID
Max OD
Min ID
in.
in.
mm
in.
mm
4 x 3.250
4-1/2 x 3.250
5-1/2 x 4.000
5-1/2 x 4.400
6-5/8 x 4.400
5.020
5.020
6.540
6.540
7.675
127.51
127.51
166.12
166.12
194.95
3.250
3.250
4.000
4.400
4.400
82.55
82.55
101.60
111.76
111.76
Model GPV Set Shoe
APPLICATION
The Model GPV gravel pack set shoe is a dual check valve used
to allow circulation out the bottom of a screen assembly to aid in
placement or retrieval of the screen in an open hole. To facilitate a
circulation path through the shoe, washpipe must be run inside the
screen and sealed in an o-ring seal sub or anti-hydraulic lock seal
bore located between the screen and the shoe. The check valves in
the Model GPV gravel pack set shoe open to allow circulation with
approximately 100 psi (689 Kpa) differential pressure from above.
During gravel packing and/or production, the check valves close to
prevent fluid or sand flow through the shoe; thereby, diverting flow
through the screens. Metallurgy of all Model GPV gravel pack set
shoe components is selected to resist corrosion and maintain a sand
tight seal for the life of the well.
Model GPV Set Shoe
53
Gravel Pack Quick Connect
APPLICATION
The gravel pack quick connect is used to simplify the connection of long gravel pack
packer assemblies to the screen liner. The tool consists of an upper and lower half
which are joined with a sleeve. The upper half of the tool is typically run immediately
below the gravel pack extension. The lower half of the tool is run at the top of the
screen liner. The connection is made by simply stabbing the upper half of the quick
connect into the lower half and making up the sleeve to hold the two halves together.
The quick connect eliminates the need to rotate the gravel pack packer assembly,
which is often difficult due to the length and weight of the assembly. In addition,
eliminating the need to rotate removes the risk of backing-off internal threads in the
gravel pack assembly.
Features/Benefits
 Eliminates
rotation and speeds makeup time for gravel pack
packer assembly
 Reduces risk of damaging threads during makeup
 Improves safety during makeup
 High tensile, rotationally locked connection adequate for most
gravel pack applications
SPECIFICATION GUIDE
Size ID
Max OD
Min ID
in.
in.
mm
in.
mm
5
7
5.560
7.812
141.22
198.43
3.958
6.000
100.53
152.40
54
BetaBreaker Valve
APPLICATION
The BetaBreaker™ valve is designed to facilitate placement of External Casing Packers (ECP's™)
within an openhole horizontal gravel pack. Use of the patented system allows gravel packing to
be performed prior to setting the ECP's without depositing gravel in the ECP/openhole annulus.
Following gravel packing, the ECP can be set against the formation face to form a positive
mechanical seal. This eliminates the need to gravel pack between previously set ECP's or
having to divert the gravel around the ECP's.
The BetaBreaker valve also has applications in long, horizontal gravel packs not using ECP's where
the formation will not withstand the pressure required for gravel placement using conventional
techniques. Utilizing a single or multiple BetaBreaker valves in the washpipe string will reduce overall
pump pressure requirements by effectively shortening the washpipe flow path as the pack progresses.
This essentially eliminates restrictions on gravel pack lateral length in pressure sensitive formations.
The BetaBreaker valve(s) is run on the inner washpipe string inside the screen liner and seals off inside
ECP in the screen liner, or polish bore receptacle (PBR) in non-ECP applications, using a bonded seal
stack. As the gravel packing begins the Alpha-wave forms and “jumps” over each ECP by exceeding
critical sand transport velocity due to the increased OD for the ECP as compared to the screen. When
the Betawave covers the screen below the lowermost ECP (or PBR) position, a mini-screenout occurs
due to the seals on the BetaBreaker valve blocking the fluid return path in the screen liner/washpipe
annulus. The mini-screenout results in a pressure differential that causes the BetaBreaker valve to trip.
Tripping opens annular ports and establishes a new return flow path into the washpipe through the
screen section above the ECP (or PBR).
Features/Benefits
 BetaBreaker
valve and ECP combination allows positive mechanical zonal isolation in
long, openhole, horizontal gravel packs
 Allows gravel packing in a single stage using proven Alpha-wave and Beta-wave
placement techniques. The ECP's are set in a separate trip
 BetaBreaker valves allow “shortening” of the effective washpipe length during the
gravel packing operation, thus reducing pump pressure during Beta-wave placement
 Field-proven bonded seal system utilized for BetaBreaker valve-to screen liner seal
 Any number of valves may be used in series in the washpipe string, all with the same
tripping pressure setting
 Tensile strength comparable to standard washpipe thread strengths
BetaBreaker Valve
55
56
Model GPR-6 and GPR-24 Shear-Out Safety Joint
Product Family Nos. H48659 and H48661
APPLICATION
The Model GPR-6™ and GPR-24™ shear-out safety joints are upstrain type releasing tools designed
for use in gravel pack applications between the gravel pack extension and the screen liner to
provide a means of releasing and retrieving the gravel pack packer independently from the screen
liner assembly. The tools consist of a top sub and bottom sub sealed together and held in place
with shear screws. The type and number of shear screws can be varied to achieve the desired
releasing force. A heavy-duty rotational lock mechanism allows torque transfer through the tools.
The Model GPR-6 shear-out safety Joint provides 6-in. (152-mm) of seal surface “stroke” after the
tool is sheared. The Model GPR-24 shear-out safety joint provides 24-in. (609-mm) of seal surface
“stroke” after the tool is sheared.
Note: Hydraulic forces during gravel packing can actuate shear-out safety joints; thus, they should
be used only when a firm base exists for the gravel pack assembly. This typically limits the use of
shear-out safety joints to cased hole environments.
Features/Benefits
 Provides
a means to retrieve the gravel pack packer independently of the
screen liner
 Rotationally locked for torque transfer
 Adjustable shear rating
 Available with either 6-in. (152-mm) or 24-in. (609-mm) seal surface “stroke”
after tool is sheared
SPECIFICATION GUIDE
Model GPR-6 and GPR-24 Shear-Out Safety Joint
Size ID
Max OD
Min ID
in.
in.
mm
in.
mm
1.900
2-3/8
2-7/8
3-1/2
4
4-1/2
5
5-1/2
6-5/8
7
2.345
2.910
3.460
4.180
4.600
5.000
5.560
6.060
7.430
7.625
59.5
73.9
87.8
106.2
116.8
127.0
141.2
153.9
188.7
193.7
1.610
2.000
2.440
3.000
3.550
4.000
4.410
4.950
5.940
6.365
40.9
50.8
61.9
76.2
90.2
101.6
112.0
125.7
150.9
161.7
Model GPR-6 and GPR-24
Shear-Out Safety Joint
57
Model S-22 Locator Seal Assembly
APPLICATION
The Model S-22™ locator seal assembly is used in single-packer, single-zone, or
dual-zone installations to provide an efficient, leakproof seal between the packer
and the production string. Standard applications include those where the tubing
is landed with weight on the packer and/or where tubing is allowed to float.
Model S-22 Anchor Seal Assembly
APPLICATION
The Model S-22 anchor seal assembly is used in the same applications as
locator seal assemblies but has a latch in addition to the locating shoulder for
connection to the packer. The latch, in conjunction with the left-hand square
threads located on top of the packer body, locks the tubing string into the packer.
When properly landed in the packer, tubing tension will be held by the latch,
preventing seal movement.
Model S-22 Seal Nipple
APPLICATION
The Model S-22 seal nipple is used in combination with a locator, snap-latch,
or anchor seal assembly to seal in the auxiliary seal bore(s) of a gravel pack
completion or the lower packer(s) of a multiple-packer completion.
Model S-22 Locator
Seal Assembly
Model S-22 Anchor
Seal Assembly
Model S-22 Seal Nipple
58
Model S-22 Snap-Latch Seal Assembly
APPLICATION
The Model S-22™ snap-latch seal assembly provides a leakproof seal between the
packer and the production string. It is ideally suited for all applications requiring a
snap-in/snap-out indication that the seals are in or out of the packer bore.
The snap-latch seal assembly is most often run on the bottom of an upper gravel pack
assembly in a dual-zone completion. It is latched into the top packer of the lower gravel
pack to guarantee the production seals are properly seated and the upper-zone gravel
pack assembly is in the proper location. The S-22 snap-latch is also used in single-zone
completions to provide an indication that the gravel pack assembly is properly landed in
the sump packer.
Model S-22B Snap-Latch Seal Assembly
Model S-22 Snap-Latch
Seal Assembly
APPLICATION
The Model S-22B™ snap-latch seal assembly provides a leak proof seal between the
packer and production string. Similar to the Model S-22, it allows a snap-in/snap-out
indication when the seals are located within the seal bore of the packer.
The difference between the S-22 and the S-22B is that the S-22B has a polished seal
bore to allow isolation from the upper or lower zone. It is latched into the lower gravel
pack packer to guarantee the seals are properly seated and the upper gravel pack
assembly is properly located.
Polished
Seal Bore
Model S-22B Snap-Latch
Seal Assembly
59
Model S-22 Multiple Acting Indicator Seal Assembly
APPLICATION
The Model S-22™ multiple acting indicator seal
assembly is designed to provide positive location of
a gravel pack assembly into a permanent type sump
packer. This seal assembly is ideal for use in highly
deviated wells or when working from a floating rig.
The assembly consists of a locator with bonded
seals for setting down weight on the sump packer
and providing a leakproof seal. Below the seals is a
spacer tube and multiple acting indicator collet. The
collet is designed to compress and pass through the
packer bore, and is spaced-out to be approximately
3 ft (0.9 m) below the bottom of the packer when
the locator contacts the top of the packer. Below the
collet is a production tube with fullmuleshoe and
kickover lug to ensure the tool enters the bore of the
sump packer without damage.
In operation, the Model S-22 multiple acting indicator
seal assembly is run on the bottom of the gravel
pack assembly. Set-down weight of approximately
2,000 to 4,000 lb (907 to 1,814 kg) pushes the collet
through the bore of the sump packer. Additional
slack-off causes the locator to set on the top of the
sump packer providing a positive set-down weight
indication. Picking up approximately 3 ft (0.9 m)
causes the indicating collet to contact the bottom of
the sump packer where an overpull of approximately
6,000-15,000 lb (2,721-6,803 kg) can be applied
before the collet compresses and pulls through the
packer bore. Thus, positive surface indications of setdown and overpull with approximately 3 ft (0.9 m) in
between provides assurance the Model S-22 multiple
acting indicator seal assembly is correctly located in
the sump packer.
Features/Benefits
 Provides
surface set-down and overpull
indications to insure positive location
of the seal assembly in the bore of the
sump packer to verify location of the
gravel pack assembly
 Provides for multiple slack-off and
pickup indications with a known distance
in between
 Provides a positive seal in the sump
packer for gravel pack applications
Model S-22 Snap-Latch
Seal Assembly
SPECIFICATION GUIDE
Model S-22 Multiple Acting Indicator Seal Assembly
Tool Size
Max OD
Min ID
Standard Connection
Upstrain Rating of Collet
in.
mm
in.
mm
in.
mm
lb
kg
20-25
3.125
79.3
1.610
40.8
2-3/8
60.3
6,000 - 8,000
2,721 - 3,628
40-26
3.062
77.7
1.988
49.9
2-3/8
60.3
6,000 - 8,000
2,721 - 3,628
40-30
3.187
80.9
1.968
49.9
2-3/8
60.3
8,000 - 10,000
3,628 - 4,535
80-32
3.465
88.0
2.406
61.1
2-7/8
73.0
8,000 - 10,000
3,628 - 4,535
80-40
4.218
107.1
2.992
75.9
3-1/2
88.9
12,000 - 14,000
5,443 - 6,350
190-47
4.875
123.8
3.500
88.9
4-1/2
114.3
13,000 - 15,000
5,896 - 6,803
190-60
6.250
158.7
4.875
123.8
5-1/2
139.7
13,000 - 15,000
5,896 - 6,803
Model A Ratcheting Muleshoe
APPLICATION
The Model A™ ratcheting muleshoe facilitates
the stabbing of seal assemblies and production
equipment into packers, especially those set in
deviated wellbores. It allows the operator to rotate
the muleshoe and production assembly by setting
60
down and picking up the workstring, where as
regular muleshoes must be rotated to enter the
packer bore. The Model A ratcheting muleshoe will
index 120o with as little as 75 lb (34 kg) set-down
weight and continue to index as often as necessary.
Model A
Ratcheting Muleshoe
Screens
BAKERWELD Screen
Product Family Nos. H48605, H48606, H48634, H48645, H48646, and H48647
APPLICATION
BAKERWELD™ gravel pack screen is a sand-retention device set in the well to provide a simple, reliable, and effective
method of preventing gravel pack sand from entering the tubulars while allowing production fluid to flow into the
well. The wire wrap design has almost 10 times more inflow area than slotted pipe of the same opening size, which
increases well longevity. BAKERWELD screens are constructed with keystone shaped wire, allowing a self-cleaning
action for greater flow and less chance of plugging. Each wire is welded at every point of contact with the underlying
rib wire so it does not separate when pulled or “birdnest” when milled, offering superior fishability. Pull tests are
performed on the wire to rib weld to insure the highest strength and durability. For additional strength the screen
jackets are welded directly to the base pipe using ASME Section 9 welding procedures and certified welders. All
BAKERWELD screens are manufactured according to documented Quality Control Procedures which are available
for review at the screen-manufacturing sites. BAKERWELD screens offer the highest quality in wire wrap screen
technology and are available in size from 1.050-in. - 6.625-in. (26.7-mm - 168.3-mm) with a wide range of threaded
connections for use in oil, gas, waterflood, water, and disposal wells. A wide range of metallurgies is available for the
jacket construction as well as the base pipe.
Features/Benefits
 BAKERWELD screens offer superior fishability and millability. Because the wrap is welded at each point
of contact with the rib wire, it does not separate when pulled and does not “bird nest” when milled
 The screen can be used in oil, gas, waterflood, steamflood, water, and disposal wells
 Manufactured for quality and dependability each screen consists of continuously wrapped
keystone shaped wire which allows for self cleaning, greater flow and less chance of plugging
 L-80 base pipe offers 45% additional strength over J-55 for enhanced bending, tensile, and
torque specifications
 Premium, fit for purpose thread that provides faster field makeup, tighter bending radius, and
higher torque resistance
 The screen is designed to have up to 10 times more effective inlet area than a slotted pipe of the
same gauge for highrate gas or oil wells
SPECIFICATION GUIDE
BAKERWELD Screen
Base Pipe Size
1.050
Weight
Pipe Size ID
Coupling OD
Hole Size
No. of Holes
Standard
Hi-Flow
BAKERWELD
Screen OD
BAKERWELD 140
Screen OD
lb/ft
kg/m
in.
mm
in.
mm
in.
mm
ft
m
ft
m
in.
mm
in.
mm
1.14
1.70
0.824
20.9
1.313
33.4
3/8
9.5
30
98
60
197
1.50
38.1
1.64
41.7
1.315
1.70
2.53
1.049
26.6
1.660
42.2
3/8
9.5
30
98
60
197
1.76
44.7
1.90
48.3
1.660
2.30
3.42
1.380
35.1
2.054
52.2
3/8
9.5
36
118
72
236
2.11
53.6
2.25
57.2
1.900
2.75
4.09
1.610
40.9
2.200
55.9
3/8
9.5
42
138
84
276
2.35
59.7
2.49
63.2
2.063
3.25
4.84
1.751
44.5
2.500
63.5
3/8
9.5
42
138
84
276
2.51
63.8
2.65
67.3
2.375
4.60
6.85
1.995
50.7
2.875
73.0
3/8
9.5
48
157
96
315
2.82
71.6
2.98
75.2
2.875
6.40
9.52
2.441
62.0
3.500
88.9
3/8
9.5
54
177
108
354
3.32
84.3
3.46
87.9
3.500
9.20
13.69
2.992
76.0
4.250
108.0
3/8
9.5
66
217
132
433
3.95
100.3
4.09
103.9
4.000
9.50
14.14
3.548
90.1
4.500
114.3
3/8
9.5
72
236
144
472
4.45
113.0
4.59
116.6
4.500
11.60 17.26
4.000
101.6
5.000
127.0
3/8
9.5
78
256
156
512
4.96
126.0
5.10
129.5
5.000
15.00 22.32
4.408
112.0
5.563
141.3
3/8
9.5
84
276
168
551
5.47
138.9
5.61
142.5
5.500
17.00 25.30
4.892
125.7
6.050
153.7
3/8
9.5
90
295
180
591
5.97
151.6
6.11
155.2
6.625
24.00 35.72
5.920
150.4 7.390 
187.7
3/8
9.5
108
354
216
709
7.11
180.6
7.25
189.2
BAKERWELD Screen
 Turned-down coupling available on request.
Centering guides, Product Family No. H48531, are optional.
Recommended applications should give 2 in. (50.8 mm) radial clearance from screen OD to openhole diameter or 0.75 in. to 1.0 in. (19.1 mm to 25.4 mm)
radial clearance from screen OD to casing ID for wells with gravel pack to enable retrieval. Less radial clearance will probably make screen retrieval difficult
after producing the well because of the inability to wash over the screen to remove formation sand packed around it. Larger sizes available upon request.
61
Screens
SLIM-PAK Screen
APPLICATION
SLIM-PAK™ screen provides the benefits of a pre-packed screen without sacrificing critical OD or
ID dimensions. The screen system makes gravel packed or frac packed completions more reliable
without dimensional restrictions or performance limitations. The SLIM-PAK consists of a wire cloth
wrapped around a perforated pipe base, a pre-cured layer of Baker Bond™ resin-coated proppant and a
BAKERWELD™ screen jacket welded to a perforated pipe base. The surfaced cured Baker Bond layer offers
maximum permeability and compressive strength to properly inhibit formation sand production through
annular pack imperfections making it particularly well suited for frac pack and difficult gravel placement
applications. Some wells on artificial lifts, such as rod pumps and submersible pumps, make trace amounts
of fines which cause premature equipment failure. Provided the well does not make enough sand to justify
a gravel pack, installation of a SLIM-PAK could extend the life of the downhole pumping equipment by
providing a cost effective downhole sand control solution.
SLIM-PAK screen is available in a large variety of sizes and metallurgy and, like our BAKERWELD screens,
are manufactured according to documented Quality Control Procedures which are available for review at
the screen manufacturing sites.
Features/Benefits
 The SLIM-PAK restricts formation sand production through pack imperfections
 The Baker Bond is surface cured after assembly to ensure maximum permeability and compressive strength
 The SLIM-PAK ensures zone coverage when close spacing between zones limits the gravel reserve
 The SLIM-PAK is particularly well suited for long intervals and highly deviated or horizontal applications
 The slender construction eases passage through tight spots and “doglegs”
SPECIFICATION GUIDE
SLIM-PAK Screen
Pipe Size
Weight
Pipe ID
Coupling OD
Screen OD
No. of Holes (ft)
Standard
Hi-Flow
BAKERWELD
Screen OD
lb/ft
kg/m
in.
mm
in.
mm
in.
mm
/ft
/m
/ft
/m
in.
mm
1.050
1.14
1.70
.824
20.9
1.313
33.4
1.64
41.7
30
98
60
197
.375
9.5
1.315
1.70
2.53
1.049
26.6
1.660
42.2
1.90
48.3
30
98
60
197
.375
9.5
1.660
2.30
3.42
1.380
35.1
2.054
52.2
2.25
57.2
36
118
72
236
.375
9.5
1.900
2.75
4.09
1.610
40.9
2.200
55.9
2.49
63.2
42
138
84
276
.375
9.5
2.063
3.25
4.84
1.751
44.5
2.500
63.5
2.65
67.3
42
138
84
276
.375
9.5
2.375
4.60
6.85
1.995
50.7
2.875
73.0
2.96
75.2
48
157
96
315
.375
9.5
2.875
6.40
9.52
2.441
62.0
3.500
88.9
3.46
87.9
54
177
108
354
.375
9.5
3.500
9.20
13.69
2.992
76.0
4.250
108.0
4.09
103.9
66
217
132
433
.375
9.5
4.000
9.50
14.14
3.548
90.1
4.500
114.3
4.59
116.6
72
236
144
472
.375
9.5
4.500
11.60
17.26
4.000
101.6
5.000
127.0
5.10
129.5
78
256
156
512
.375
9.5
5.000
15.00
22.32
4.408
112.0
5.563
141.3
5.61
142.5
84
276
168
551
.375
9.5
5.500
17.00
25.30
4.892
125.7
6.050
153.7
6.11
155.2
90
295
180
591
.375
9.5
6.625
24.00
35.72
5.920
150.4
7.390
187.7
7.25
184.2
108
354
216
708
.375
9.5
Recommended applications should give 2 in. (50.8 mm) radial clearance from screen OD to openhole diameter or 0.75 in. to 1.0 in. (19.1 mm
to 25.4 mm) radial clearance from screen OD to casing ID for wells with gravel pack to enable retrieval. Less radial clearance will probably make
screen retrieval difficult after producing the well because of the inability to wash over the screen to remove formation sand packed around it.
62
SLIM-PAK Screen
Screens
EXCLUDER2000 Screen
APPLICATION
EXCLUDER2000™ is a premium downhole sand exclusion device that incorporates the industry
proven EXCLUDER™ screen sand retention and longevity technology with enhanced mechanical
strength and integrity. EXCLUDER2000 employs a unique manufacturing process enabling the
individual components to act as one creating a stronger more durable product. Additionally a
more robust filtration membrane juncture and cartridge seal design has been incorporated. The
EXCLUDER2000 screen's improved design has increased it's already proven ability to perform
in the most challenging of environments including openhole horizontals, short radius wells,
re-entries, and offers added protection for any gravel pack/frac pack situation.
Features/Benefits
 EXCLUDER2000 is available in a variety of micron ratings and metallurgies to optimize
performance in a wide range of well environments
 The BAKERWELD inner jacket screen opening is sized 25 μm larger than the vector
membrane, offers secondary formation solids control and acts as a drainage layer with
superior flow convergence due to the wire's geometry
 The vector membrane provides an increased inflow area, minimizing problems associated
with high inflow velocities. The uniform openings (in the weave) allow for stringent sizing
quality control during the manufacturing process and greater accuracy in selecting the
proper weave size to formation particle size
 The vector shroud allows for safe placement without worrying about the screen's integrity
once in place. This field-proven design also provides flow diversion during production which
increases the screens longevity by minimizing erosional effects from formation material
 By mounting the filter cartridge on perforated base pipe maximum tensile, compression
and collapse performance is achieved. The pipe is available in standard oil field sizes to
cover most hole sizes
PORT SIZE AVAILABILITY
Size
Formation Type
Description
Fine
Medium
Coarse
100µm < d10 < 200µM
200µm < d10 < 300µM
d10 > 300µM
High Sand retention efficiency
Allows for conditioned mud flowback
Minimum fines pligging and maximum mud flowback capacity
SPECIFICATION GUIDE
EXCLUDER2000 Screen
Base Pipe
Size
Base Pipe
ID
Screen OD
Weight
in.
lb/ft
kg/m
in.
mm
in.
mm
lb/ft
kg/m
3-1/2
4
4-1/2
5-1/2
6-5/8
7
9-5/8 
9.20
9.50
11.60
17.00
24.00
26.00
43.50
13.69
14.14
17.26
25.30
35.71
38.69
64.73
2.992
3.548
4.000
4.892
5.920
6.276
8.775
74.22
90.12
101.60
124.25
150.36
159.41
222.88
4.30
4.80
5.31
6.32
7.46
7.89
10.54
109.22
121.92
134.87
160.53
189.48
200.40
267.72
14.4
15.2
18.3
25.7
33.5
36.7
57.5
21.43
22.62
27.23
38.24
49.85
54.61
85.56
EXCLUDER2000 Screen
Product Family Nos. H48690
and H48691
Recommended applications should give 2 in. (50.8 mm) radial clearance from screen OD to openhole diameter or 0.75 in. to 1.0 in.
(19.1 mm to 25.4 mm) radial clearance from screen OD to casing ID for wells with gravel pack to enable retrieval. Less radial
clearance will probably make screen retrieval difficult after producing the well because of the inability to wash over the screen to
remove formation sand packed around it.
 Based on EXCLUDER coarse only.
63
Screens
EXPress Screen
APPLICATION
The EXPress™ screen is a premium downhole sand exclusion device that can be expanded
outward to the wellbore or casing. It combines the proven sand control ability of the EXCLUDER™
screen with the additional benefits of screen expansion such as annular flow reduction, hole
stability, and large inside diameters. As with EXCLUDER screen it's unique filter membrane
construction allows for the production of mud solids without plugging the screen while still
maintaining effective sand exclusion. The EXPress screen's design based on perforated pipe
expansion technology, adds tremendous mechanical strength, and reliability to the screen.
Unique to the EXPress screen design is the secondary filtration layer above the vector weave
and below the protective shroud, which greatly enhances the vector weave's resistance to
plugging. Laboratory tests have shown this enhancement to yield more than twice the particle
holding capacity than that of vector weave alone for typical formation sands. This translates
to better production characteristics and greater well longevity.
With the advantage of superior sand retention and mechanical properties along with reduced/
alleviated annular flow and a reliable expansion system independent of pipe weight, the
EXPress screen can be offered as the best mechanical solution for both gravel pack and/or
stand-alone screen applications where production longevity is paramount.
Features/Benefits
 Functions
as a premium sand exclusion device whether or not it is expanded
 New secondary filtering system improves the particle holding capacity of the screen
 The solids controlling layer of the filter membrane is the same as the proven
EXCLUDER screen
 Installation is easy using conventional equipment
 Rugged construction insures the product is not compromised during installation
 Mechanical performance is similar to that of regular pipe based screen
 Provides sand exclusion with an ID larger than possible with a standard screen
 Greatly reduces annular flow around the screen, preventing sand migration and
the development of “hot spots”
SPECIFICATION GUIDE
EXPress Screen
Size
64
OD
ID
Expanded OD
Screen Joint Length
in.
lb/ft
kg/m
in.
mm
in.
mm
ft
m
4.750
6.875
5.160
7.285
131.1
185.0
4.190
6.235
106.4
158.4
5.028
7.482
127.7
190.0
20
6.1
EXPress Screen
Screens
EQUALIZER Screen
APPLICATION
The EQUALIZER™ is an innovative reservoir drainage system that integrates two proven
Baker Hughes technologies—the EXCLUDER2000™ premium well screen, and a specially
designed Inflow Control Device (ICD) that optimizes production and delays water or gas coning in
long, low-draw down, high-rate horizontal wells. The system balances, or equalizes, longitudinal
inflow along the entire length of the wellbore to ensure a uniform production profile. Additionally
the EQUALIZER greatly reduces annular flow by controlling the resistance to flow for each screen.
The inflow control device is constructed of a unique helical flow channel as a governing
element to impose a pressure distribution along the entire length of the wellbore. In this way,
it can control the local production rate through each individual screen along the wellbore as a
function of both the average drawdown pressure and the average productivity of the well. The
special design of the ICD induces the subsequent flow regulation without any moving parts or
elastomer seals which enhances the products reliability.
Computer modeling allows the system to be configured with precise combination of crosssectional area and length of channels to provide optimal pressure drop versus flow rate
characteristics to balance well inflow, based on a particular set of information data.
Often the well characteristics change from initial flow input used to select the desired
ICD however, the design of the EQUALIZER enables it to act as a self governing device
compensating for changes in flow rate.
Features/Benefits
 Increased
production by equalized production from heel to toe
 Uses proven EXCLUDER screen technology
• Components of the EXCLUDER screen are engineered for use in a wide range
of reservoirs and operating environments and are available in multiple
metallurgys and micron ratings
• BAKERWELD inner jacket adds proven durability - The inner membrane is
supported by the fieldproven BAKERWELD inner jacket, safely protecting the
vector weave when encountering high differential pressures. Additionally, the
inner jacket’s gauged openings are sized 25 microns larger than the membrane
openings, providing secondary formation control
SPECIFICATION GUIDE
EQUALIZER Screen
Size
OD
ID
Expanded OD
Screen Joint Length
in.
lb/ft
kg/m
in.
mm
in.
mm
ft
m
4.750
6.875
5.160
7.285
131.1
185.0
4.190
6.235
106.4
158.4
5.028
7.482
127.7
190.0
20
6.1
EQUALIZER Screen
65
66
S e r v i c e To o l s
Model CS Crossover Tool
APPLICATION
The Model CS™ crossover tool, in conjunction with the Model CS gravel pack
extension, directs and controls the fluid flow path through the Model CS-300™
gravel pack system. The CS crossover tool preserves openhole integrity by
maintaining a hydrostatic overbalance to the formation during all phases of the
gravel pack operation, including packer setting and testing, as well as crossover
tool manipulation. The tool prevents pressure surges to the formation during
packer setting operations. The large bypass flow area minimizes back pressure
applied to formation during gravel packing. The Model A SMART Collet™ is
incorporated in the system to locate and maintain all critical crossover tool
positions with set-down weight.
Model CS-AP Crossover Tool
APPLICATION
The Model CS-AP™ crossover tool is a modification of the standard CS-300
crossover tool that enables the tool to be used for post-gravel pack formation
chemical treatments or external casing packer inflation. After completion of the
gravel pack, a conversion ball is pumped down to a ball seat in the bypass tube.
Applied tubing pressure isolates the return and bypass ports and redirects the
fluid flow path to the ID of the washpipe.
Model CK Crossover Tool
APPLICATION
The Model CK™ crossover tool is optimized for the extreme pump velocities and
proppant volumes required in high-pressure frac pack sand control applications.
The tool includes features that maximize wear life, minimize tool drag, increase
torque, tensile, burst, and collapse strength, as well as facilitate proppant
cleanup after well treatment. The CK FRAQ™ port incorporates the ball catcher
subassembly that captures and holds the primary setting ball. The isolation
sleeve in the ball catcher enables the crossover tool to function as a pressure
tight conduit through the frac assembly until the sleeve is opened with applied
tubing pressure.
Model CS-300
Crossover Tool
Model CK
Crossover Tool
67
Model S2P and S2PH Crossover Tools
Product Family Nos. H44572, and H44566
APPLICATION
The Models S2P™ and S2PH™ crossover tools are designed
to provide the ability to circulate to the bottom of a gravel
pack assembly to aid in washing through debris, displacing
fluid, or spotting fluid. The open straightthrough bore provides
a pressure-tight circulation path during run-in. While the
S2P requires 12-15 turns of right-hand rotation to release
from the packer, the S2PH can be released hydraulically
or mechanically.
Model S2P Crossover Tool
Features/Benefits
 Teflon
ball seat prevents gravel bypass to washpipe
 After shifting, the gravel pack sleeve is mechanically held in
the gravel pack/crossover position by a snap ring
 The seal location on these tools is identical to existing
S2™ and S2H™ crossover tools so that operational space
outs and accessory equipment are not changed
 The S2 and S2H crossover tools can be converted to the
S2P™ and S2PH™ versions by replacing the appropriate parts
(e.g., the bypass tube and bypass sub)
 These crossover tools have 5,000 psi (34.5 MPa) differential
pressure ratings
®
Model S2PH Crossover Tool
Teflon is a registered trademark of Dupont.
68
Model BSC-R Gravel Pack Crossover Tool
APPLICATION
The Model BSC-R™ gravel pack crossover tool is a rotationally locked version of
the Model S2H™ crossover tool (Product Family No. H44546) developed for use
with the Model SC-1R™ packer and the Model SC-2R™ packer in highly deviated
or horizontal wells. Model BSC-PR™ (Product Family No. H44574) incorporates
pump through capability.
Features/Benefits
 The
tool has straight threads with square shoulders in all
connections that transmit torque
 The one-piece torque transmitting lugs give additional strength
and reliability
 Straight-pull release can be accomplished after applying
annulus pressure
 The rotational lock disengages automatically with applied
tubing pressure, allowing emergency right-hand release from
the packer The tool can be easily converted for use as a
long-stroke or short-stroke version tool
The rubber-coated steel ball in the bottom of the tool prevents sand from
settling inside the liner and sticking the washpipe and also restricts
pressure on the formation during reversing operations. The extra seals
allow the operator to pick up and position the bypass crossover ports in
or above the packer bore and still have seals in the seal bore sub. This
prevents sand inside the tubing from falling into the liner while pulling
the crossover tool from the gravel pack assembly.
Model BSC-R Gravel Pack Crossover Tool
69
(System Multi-Acting Repositioning Tool)
APPLICATION
The Model A SMART Collet™ is a multi-acting locating device that positively locates and
maintains crossover tool position utilizing applied set-down weight. The tool facilitates
the ability to counter dynamic forces on downhole tools due to pressure and temperature
changes, as well as changes in pipe tension due to rig heave on offshore vessels. Straight
up and down movement allows the operator to manipulate the tool into either a locating
or snap through mode. This allows the tool to either locate on the locating shoulder in
the indicating coupling or snap through the indicating coupling. The collet cannot be
inadvertently pushed through the indicating coupling while in the locating mode.
Features/Benefits
 Collet
is always positioned in a retrieving mode
 Collet is manipulated to the different positions by applying set-down
weight against the indicating coupling
 Requires approximately 4,000 to 6,000 lb (1,814 to 2,722 kg) set-down
weight to snap through the indicating coupling
 Requires approximately 700 lb (318 kg) set-down weight to position collet
in the locating mode
 Multiple indicating couplings can be run to indicate different positions
FASTool (Flapper Anti-Swabbing Tool)
FASTool
(Flapper Anti-Swabbing Tool)
APPLICATION
The FASTool™ (Flapper Anti-Swabbing Tool) is a single-acting flapper valve connected to
the lower end of a crossover tool. The FASTool is utilized to prevent formation swabbing
due to crossover tool manipulation, and to provide zonal isolation while reverse circulating
for cleanup after pumping the sand control treatment. In frac pack applications, the tool
facilitates pressure decline analysis for fluid efficiency calculations. Initially, the flapper
in the tool is run in the open position. The flapper is released and seated by pulling the
FASTool through a seal bore in the gravel pack or FRAQ Extension.
Features/Benefits
 Positive,
single-acting, protected collet actuating system
release of 21,000 lb (9,525 kg)
 Seating actuator locks into shifted (closed) position
 Shear
70
Model A Multiple Acting Indicator Collet
APPLICATION
The Model A™ multiple acting indicator collet is used in conjunction with either the
Model A indicating sub (Product Family No. H44535) or the indicating coupling
(Product Family No. H44528) to provide a positive means of locating various positions
during gravel pack operations. All collets are available in either a standard or inverted
assembly. The standard collet will indicate a weight increase at the surface due to the
upward pull of the tool against the internal locating bevel in either the indicating sub
or coupling. The inverted collet will indicate a weight decrease at the surface when
it contacts the internal locating bevel during a downward motion of the tool. Snap
forces of 5,000 - 10,000 lb (2,268 - 4,536 kg), 10,000 - 15,000 lb (4,536 - 6,804 kg), or
15,000 - 20,000 lb (6,804 - 9,072 kg) are available, depending on the specific application.
Model A Multiple Acting Indicator Collet
71
Model SC Hydraulic Setting Tool
APPLICATION
The Model SC™ hydraulic setting tool is a single-chamber, tubing pressure
actuated setting tool used in gravel pack operations in conjunction with the
gravel pack crossover tool or hydro-set adapter kit to run and set Models SC and
HP™ packers and drillable type production packers on tubing.
Features/Benefits
 Short
and compact - Increases the efficiency of handling, shipping,
and storing as well as operations on the rig
 Simple construction - Constructed of a minimum number of working
parts, making it economical to maintain
Model B-1 Hydraulic Setting Tool
APPLICATION
The Model B-1™ hydraulic setting tool is a tubing pressure actuated device used
for setting SC-type packers in smaller casing sizes.
Features/Benefits
 Multi-chambers
for maximum setting force with minimum
tubing pressure
designed for gravel packing. Gravel can be pumped
through the tool without affecting the internal mechanisms
 Run on tubing, allowing same-trip setting and testing of packer
 Designed for use with a hydro-set adapter kit or gravel pack crossover
tool, rather than a wireline adapter kit, to simplify and provide a more
positive connection between the packer and the setting tool
 Streamlined design for a wide variety of casing sizes
 Specifically
Model SC Hydraulic Setting Tool
Model B-1 Hydraulic Setting Tool
72
Closed Port Hydraulic Setting Tool
APPLICATION
The closed port hydraulic setting tool is designed to prevent premature actuation
in downhole situations of extreme tubing overbalance or pressure surges. The
hydraulic chamber of the setting tool is completely isolated from well pressures.
This allows completions to be run without any possibility of setting the packer
due to premature actuation of the setting tool. The setting tool is a single
chamber, tubing pressure actuated tool used in conjunction with a gravel pack
crossover tool to run and set Models SC™ and HP™ packers and drillable type
production packers on tubing.
Features/Benefits
 Setting
port isolated at all times, until opened by setting ball
setting ball required to open setting port, set packer and open
gravel pack port
 Low pressure to activate setting tool
 Optimized to set 7-in. (177.8-mm) through 11-3/4-in. (298.45-mm)
Models SC™ and HP™ packers
 Maximized tensile rating
 Compatible with the one-trip PERF-FRAQ™ system (positive ball catcher)
 Includes back-up ball seat
 Designed with high-pressure back-up rings on all o-rings
 Tested to function up to 8,000 psi (55.16 MPa) hydrostatic or
overbalance pressure
 One
Model HP Hydraulic Setting Tool
APPLICATION
The high pressure setting tool is a multi-chamber, tubing pressure actuated
setting tool used in gravel pack operations in conjunction with gravel pack
crossover tool or hydro-set adapter kit to run and set model SC and HP packers
and drillable type production packers on tubing.
Closed Port Hydraulic
Setting Tool
Features/Benefits
 Features back-up rings, which provides increased pressure rating
 Multi-chambers for maximum setting force with minimum tubing pressure
 Specifically designed for gravel packing. Gravel can be pumped through
Model HP Hydraulic
Setting Tool
the tool without affecting the internal mechanisms
 Streamlined design for a wide variety of casing sizes
 Simple construction - Constructed of a minimum number of working
parts, making it economical to maintain
73
Model BSC-R Hydro-Set Adapter Kit
APPLICATION
The Model BSC-R™ hydro-set adapter is used in conjunction with the Model SC™ hydraulic setting tool
with special pin down (Product Family No. H44521) to run-in, set, and release from the Model SC-1R™
or SC-2R™ packer in highly deviated and horizontal wells.
This adapter kit features a hydraulically operated rotational lock used to transmit torque from the
workstring, through the packer, and into the screen liner below to assist running assembly to bottom.
The adapter kit incorporates a pump out ball seat which, when sheared, will allow tubing fluid to
drain and facilitate in retrieval of the setting tool and adapter kit.
Features/Benefits
 Straight
thread up with fishing neck for heavy duty use
threads with square shoulders in all connections that transmit torque
 One-piece torque transmitting lugs for added strength and reliability
 Straight pull release can be accomplished after applying annulus pressure
 Rotational lock disengages automatically with applied workstring pressure and locks itself
in the up position, allowing emergency right-hand rotation to release from packer
 Straight
Model BSC-R
Hydro-Set Adapter Kit
Model S2H Hydro-Set Adapter Kit
APPLICATION
The Model S2H™ hydro-set adapter is used in conjunction with the Model SC™ hydraulic setting
tool to run-in, set, and release from the Model SC-1™ or SC-2™ packer. The adapter kit incorporates
a pump out ball seat which, when sheared, allows tubing fluid to drain to facilitate retrieval of the
setting tool and adapter kit. After setting the packer, the adapter kit is hydraulically released from
the packer with annulus pressure. Alternatively, the adapter kit can be released from the packer by
rotating to the right fifteen turns to unscrew the latch from the left-hand square thread in the top of
the packer.
Features/Benefits
 No
rotation required, releases from the packer with a straight pull. Ideally suited for
deviated wells or floating rigs
 Emergency right-hand rotational release
Model S2H
74
Model S-1 Shifting Tool
APPLICATION
The Model S-1™ shifting tool is installed below the crossover tool to shift the multiple-acting sliding
sleeve in a Model S™, CS™, or CK FRAQ™ extension with sliding sleeve. The spring force of the
shifting tool collet causes engagement of the collet with the ID profile of the sliding sleeve and shifts
the sliding sleeve open (down) or closed (up) when the shifting tool passes through the ID of the
gravel pack sliding sleeve.
Features/Benefits
 Automatic
engage and release of sliding sleeve
engagement surface for optimized shifting force
 Compatible with both standard sliding sleeve and high rate detent sleeve
 Angled
Over the Top Gravel Pack Service Tool
APPLICATION
The Over The Top gravel pack tool is designed to place gravel by a crossover circulating type method
when running screen or liner on a landing nipple (Product Family No. H48625). The left-hand square
thread on the release nut attaches to the landing nipple while the two down-facing packer cups
direct the gravel flow down the screen/ casing annulus.
Model S-1 Shifting Tool
At a later time, if it becomes necessary to add gravel to the pack, the release nut of the Over The Top
gravel pack tool is replaced with the Over The Top repack tool (Product Family No. H48336). Its
up-facing cup seals off in the landing nipple and prevents gravel from falling into the liner ID during
the repacking operation. The release nut of the Over The Top gravel pack tool and the guide of the
Over The Top repack tool have tubing box threads for washpipe.
When running either of the two tools, it is recommended that a check valve be run below
(Product Family No. H48340). The clutch joint assembly (Product Family No. H48570) is a device
used to release a hookup nipple (Product Family No. H48532) and screen assembly by righthand
rotation of the tubing string. The tool can be used for gravel packing with or without a retrievable
packer. It can also be used with or without wash pipe run below. After gravel packing, the packoff
overshot (Product Family No. H48533) seals over the hookup nipple to complete the production string.
Features/Benefits
 The
hookup nipple and screen assembly is released by right-hand rotation of the
tubing string
 The clutch joint provides 5 ft (1.5 m) of stroke with relation to the hookup nipple and
screen assembly. This means after the screen assembly tags bottom or tags a bridge
plug, 5 ft (1.5 m) of downward stroke remains to set a packer or, as in the traditional
gravel pack hookup, enough stroke to open a pushdown shoe
 The hookup nipple can be ordered with any size centering guides to position the assembly
in the center of the casing
Over The Top Gravel
Pack Service Tool
75
Model SB Latching Type Packer Plug and Model SB Latching
Type Packer Plug With Support Mandrel and Surge Chamber
Product Family Nos. H66517, H66519 and H66520
APPLICATION
The Model SB™ latching type packer plug is used to convert SC™, D™, and F™ style packers to temporary
bridge plugs. When installed in the packer, the plug permits the operations such as pressure testing,
perforating and washing above the packer without affecting the zone below the packer. The plug is
equipped with an anchor latch and molded seals and is run on a Model SB running tool (Product Family
No. H66531). The running tool slides over the control bar of the packer plug and is shear screwed in
place. The running tool can be configured for either shear down or shear up release. Setting down
approximately 3,000 lb (1,361 kg) latches the packer plug into the packer. Slacking-off or picking up
3,000 - 6,000 lb (1,361 - 2,722 kg) (depending on number of shear screws) releases the running tool. If
debris settling on or around the packer plug is anticipated, gravel pack sand should be spotted over the
plug to cover the control bar. The packer plug is retrieved with a Bowen™ overshot. The overshot should
be equipped with a skirt to facilitate washing debris down to the top of the packer. After thoroughly
washing around the plug, the overshot is latched onto the control bar. Straight pull of 6,000 - 8,000 lb
(2,722 - 3,629 kg) shears the release mechanism of the plug and allows pressure equalization across the
plug to allow it to be pulled out of the packer and retrieved. Alternately, the plug can be released with
15 turns right-hand rotation while holding a slight upstrain.
As the packer plug enters the packer, fluid is displaced ahead of the plug. The volume of fluid displaced
must be compressed or absorbed (typically by a large sump area or open perforations) to fully insert
and latch the plug. In the event the area below the packer is a closed area, the Model SB latching
type packer plug with surge chamber must be used. The surge chamber contains a piston that shears
and moves up as the plug enters the packer bore to absorb the fluid volume displaced. Running and
releasing of the Model SB latching type packer plug with surge chamber is identical to that of the
standard Model SB latching type packer plug.
Model SB Latching
Type Packer Plug
A support mandrel has been incorporated into the packer plug with surge chamber to allow for the
combined ability to prevent gun shock damage to the packer and prevent excessive pressure build-up
when stabbing into Model SC or retainer production packers with little or no sump area or which have
an isolated formation below.
SPECIFICATION GUIDE
Features/Benefits
 Converts
packer to temporary bridge plug
 Straight pull release with Bowen overshot
or optional emergency release with righthand rotation
 Convertible to locator type packer plug by
removing latch
 Full support/protection of the seal bore the
entire length of the body
Model SB Latching Type Packer Plug
Tool Size
Control Bar OD to Catch with Overshot
in.
mm
40DA-32
2.650
67.3
80-32
2.650
67.3
80-40
2.650
67.3
80SCA-40
2.650
67.3
80SCA-47
2.650
67.3
190-47SP
2.650
67.3
190-47
3.687
93.6
190-60
3.687
93.6
190-FA75
3.687
93.6
Model SB Latching
Type Packer Plug
With Surge Chamber
76
Model S-1 Retrieving Tool
APPLICATION
The Model S-1™ retrieving tool is used to release
and retrieve (in a single trip) all SC™ and HP™ style
packers, including large bore, alternate bore,
rotationally locked and hydraulic set versions. The
tool consists of an anchor latch at the upper end
and a spring-loaded catch sleeve at the bottom.
The tool is run in the hole and circulation is used
to thoroughly wash sand or other debris out of the
area immediately above the packer. After washing
is complete, the retrieving tool is lowered into
the packer. Application of 15,000 lb (6,804 kg)
set-down weight snaps the anchor latch into the
left-hand square threads in the top of the packer
to positively engage the packer. At this point
the tool is positioned for the packer releasing
operation. Straight pull with the workstring causes
the catch sleeve to contact the lower end on the
collet support of the packer. Overpull of 18,000 lb
(8,165 kg) shears the collet support to release the
packer. Continued upward movement transfers the
retrieving force to the body of the packer.
The Model S-1 retrieving tool is designed with
a tool joint and ACME connections for superior
strength and durability. Drill collars and jars can
be run to aid in packer release and retrieval.
Flat surfaces on the anchor mandrel and
catch sleeve mandrel provide superior jarring
surfaces. The mandrel has a keyway and is
keyed to the anchor mandrel allowing rotation
in any position. The retrieving tool can be
released from the packer at any time by picking
up slightly and rotating ±15 turns to the right.
Features/Benefits
 Release
and retrieval of SC and HP style
packers in a single trip
 Tool joint and ACME connections for
superior strength
 Suitable for use with drill collars and jars
to aid in packer release and retrieval
SPECIFICATION GUIDE
Min Retrieving Extension Dimensions
Size
To Retrieve Packer Size
25
45-25
26
32HX-23
50-26
55-26
55-32 x 26 (with 36 in. (914 mm) Upper Bore)
ID
Length
Top Connection
in.
mm
ft
m
in.
2.80
71.1
3
0.9
2-3/8 IF
2.95
74.9
3
0.9
2-3/8 IF
2.95
74.9
2
0.6
2-3/8 IF
3.68
93.5
3
0.9
2-7/8 IF
3.68
93.5
3
0.9
2-7/8 IF
4.50
114.3
2
0.6
2-7/8 IF
4.50
114.3
2
0.6
2-7/8 IF
4.50
114.3
2
0.6
2-7/8 IF
4.50
114.3
2-7/8 IF
66-32
32
70-32
76-32
40H-32
40
40H
47-40
47HX-40
70-40 x 32
70-40
76-40
96-40
70-47 x 40
76-47 x 40
70-47 x 40 (with 44 in. (1,118 mm) Upper Bore)
86-47
96-47
47
107-47
5.18
131.6
117-47
133-47
60-47
60
60H
75-60
133
96-60 x 47
107-60 x 47
96-60
107-60
117-60
107-75 x 60
117-75 x 60
200-133
2
0.6
3
0.9
2
0.6
3
0.9
3
0.9
4
1.2
2-7/8 IF
5.18
131.6
2-7/8 IF
6.43
163.3
2
0.6
3-1/2 IF
6.43
163.3
2
0.6
3-1/2 IF
6.43
163.3
2
0.6
3-1/2 IF
13.93
353.8
2
0.6
3-1/2 IF
77
pACKER SIZE/ACCESSORY SIZE GUIDE
Models SC and HP Packers
Accessory / Size
Setting Tool
Crossover Tool
Gravel Pack
Extension
Shifting Tool
Retrieving Tool
20 “B-1”
20-25
20-25
20-25
25
20 “B-1”
20-26
20-26
20-26
26
20 “B-1”
20-26
40 “B-1”
40-26
40-26
40-26
26
40SCA-32
40-26
40-26
32HX-26 
40 “B-1”
80-32
80-32
80-32
32
70 ”SC”
80-32
80-32
80-32
32
70 ”SC”
80SCA-40
80-32
80-32
40H-32
70 ”SC”
80-40
80-40
80-40
40
70 ”SC”
80SCA-47
80-40
80-40
47-40
70 ”SC”
80-32
80-32
80-32
32
70 ”SC”
80-40
80-40
80-40
40
70 ”SC”
80SCA-47
80-40
80-40
47-40
45A-25
45B-25
45C-25
50A-26
50B-26
55A2-26
55A4-26
55B-26
55C-26
55A2-32 x 26
55A4-32 x 26
55B-32 x 26
66A2-32
66A4-32
20 “B-1”
40 “B-1”
70A2-32
70A4-32
70B-32
70C-32
70A2-40 x 32
70A4-40 x 32
70B-40 x 32
70C-40 x 32
70A4-40
70B-40
70C-40
70A4-47 x 40
70B-47 x 40
70C-47 x 40
76A2-32
76A4-32
76B2-32
76B4-32
76A2-40
76A4-40
76B2-40
76B4-40
76A2-47 x 40
76A4-47 x 40
76B2-47 x 40
76B4-47 x 40
 HX designates extended packer upper bore.
78
pACKER SIZE/ACCESSORY SIZE GUIDE
Models SC and HP Packers (Continued)
Accessory / Size
Setting Tool
Crossover Tool
Gravel Pack
Extension
Shifting Tool
Retrieving Tool
86 “SC”
120-47
120-47
120-47
47
86 “SC”
190-40
190-40
80-40
40H
86 “SC”
190-47
190-47
190-47
47
86 “SC”
190SA-60 X 47 
190SA-40
80-40
60H-40
86 “SC”
190SA-60 X 47 
190-47
190-47
60-47
86 “SC”
190-60
190-60
190-60
60
86 “SC”
190-60 
198-60
190-60
60H
86A2-47
86A4-47
86AB-47
86B-47
96A-40
96A2-40
96A4-40
96B-40
96A-47
96A2-47
96A4-47
96B-47
96A-60 X 40
96A2-60 X 40
96A4-60 X 40
96B-60 X 40
96A-60 X 47
96A2-60 X 47
96A4-60 X 47
96B-60 X 47
96A2-60 
96A4-60 
96B-60 
96A-60
96B-60
96B2-60
96C-60
96C2-60
96C2-60
96C4-60
107A4-60
107A4-75 X 60
107B2-60
210-60
107 “SC”
107B2-75 X 60
117A-60
117A-75 X 60
210SCA-75
210-60
60H
198-60
190-60
210SCA-75
107 “SC”
220-60
220SCA-75
75-60
60H
75-60
198-60
190-60
60H
75-60
 “SC-1R” Only.
 Size 190-60 Hydro-Set adapter kit.
79
80
Tu b i n g - C o n v e y e d
Perforating
High Density Perforating Guns
The use of PERFFORM™ Charges at a high shot density offers
reduced perforating debris as well as improved zonal coverage
for thin, highly-laminated formations. High shot density big hole
systems provide maximum total inflow area per foot of casing,
improving sand control in gravel pack completions. The result
being significant productivity enhancements. For details on highdensity perforating guns, consult your baker hughes perforating
systems representative.
As part of Baker Hughes ongoing efforts to ensure safety and
reliable performance, our Tubing-Conveyed Perforating (TCP)
design and manufacturing operations have been ISO 9001 certified
since 1992. Demonstrating this commitment to quality, ours is
the only high-density perforating system with a high-grade steel
carrier engineered to resist splitting.
Because wellsite safety remains a top priority, our explosive test
facilities conduct quality control testing of all our TCP explosives.
This includes testing the detonation velocity of det-cords, the jet
tip velocities of shaped charges, and the output performance of all
explosive devices. The facilities can also perform high temperature
tests of explosive devices up to 600°F (315°C).
Our explosives testing facilities enable us to conduct full TCP gun system testing
in accordance with API RP43 Section 1, ensuring both wellsite safety and
charge performance.
81
Perforating
PERFFORM Charges
Minimizing Perforation Debris
PERFFORM Charges
In addition to perforation tunnels, typical TCP charges
produce carrots and coarse steel debris. This debris remains
in the wellbore. This can result in plugged perforation tunnels
that impair production and complicate the placement of gravel
pack sand. To address this issue, Baker Hughes developed
the revolutionary PERFFORM™ charge. These charges totally
eliminate carrots without sacrificing shot performance.
Patented PERFFORM charges produces debris which is easily
removed or dissolved.
Industry-leading
low-debris, carrot-free, big-hole
and deep-penetrating perforating systems
Optimum well productivity in unconsolidated formations using
big-hole charges
High shot density big-hole systems provide maximum total
inflow area per foot of casing, improving sandcontrol in gravel
pack completions
Charge debris comparison - PERFFORM charge fine-particle debris (left) vs. conventional charge steel fragments and carrots (rights)
82
Perforating
Model F Firing Head
APPLICATION
The Model F™ firing head is used to minimize the risk of gun shock
damage to the workstring and completion accessories when
detonating tubing-conveyed perforating guns in a one-trip perf/
gravel pack operation. When actuated, the firing head releases from
the workstring prior to gun detonation to prevent the transmission
of gun shock uphole. Actuation of the Model F firing head is
accomplished by bursting a rupture disc by either dropping a
detonating bar or pressuring up on the tubing. Bursting the rupture
disc forces a piston to shift towards an atmospheric chamber.
When the piston shifts, a set of support keys collapse and the
guns are released from the workstring. Hydrostatic pressure forces
the guns to move downward. After 8-in. (203-mm) of downward
movement, a port is exposed and annulus pressure bursts a second
rupture disc and drives a hammer into a detonator to fire the
perforating guns. The Model F firing head is specifically designed
to fire the guns within a pressure range of 1,500 - 14,000 psi
(10.3 - 96.5 MPa) absolute pressure (hydrostatic pressure plus
applied pressure) at the firing head.
Features/Benefits
 Reduces
the amount of gun shock damage to the
workstring and completion accessories
 Eliminates the need of shock absorbers in the workstring
 Firing head can be actuated by either dropping a bar or
applying tubing pressure
 Automatically drops the perforating guns for one-trip
perforate and complete applications
 Ideal for one-trip perforate and gravel pack applications
SPECIFICATION GUIDE
Model F Firing Head
Size
Max OD
ID After Release
Connection
in.
mm
in.
mm
in.
mm
in.
4.50
114.3
4.50
114.3
2.44
62.0
2-7/8 EUE 8rd Box Up
Model F Firing Head
83
Perforating
Horizontal Oriented Perforating
System (HOPS)
APPLICATION
The Horizontal Oriented Perforating™ System (HOPS) is used
to economically and reliably perforate long intervals in highly
deviated wellbores where orientation of the perforations is
desired. The HOPS is made up of two main components:
 Specially phased, eccentrically weighted perforating guns
 Swivel gun connectors to allow rotation of the guns
Special perforating guns are used, with the shaped charges
positioned for oriented perforating. Included in the guns are
internal, off-center weights. The position of the weights causes
the guns to rotate so that the weights are located on the bottomside of the wellbore. As the guns achieve this position, the
shaped charges are then aligned to shoot the desired orientation
into the reservoir.
Guns Firing
A swivel gun connector is included at the top of each perforating
gun section, and allows the perforating gun to freely rotate to
establish the necessary orientation. Orientation of the perforating
guns occurs as the guns enter into the deviated section of the
wellbore. No further manipulation of the workstring is required.
The swivel gun connector can be used throughout the entire
perforating gun system. For example, a recent job in the North
Sea successfully utilized 181 swivel gun connectors in one
perforating gun string, allowing oriented perforating of the
entire 5,696 ft (1,736 m) interval.
Features/Benefits
 Free
spinning swivel connector design complete with
friction-reducing bearing ring
 Faster makeup time compared to conventional oriented
TCP systems means savings in rigtime costs
 No external orienting lugs used, minimizing chances of
guns sticking
 Reliable, field-proven ballistic transfer method
 Perforation orientations and shot densities are available
for a wide variety of completion applications, including
sand control, and hydraulic fracturing
84
End View
Perforating
StimGun Assembly
APPLICATION
The StimGun™ assembly used in the Mara-Stim process is a combination perforation and perf
breakdown tool. The device consists of a perforating gun surrounded by a propellant sleeve.
SM
The StimGun assembly can be conveyed with all conventional methods: electric wireline, slickline,
tubing, or modular gun techniques. However, all aspects of the operation need to be optimized. Some
of the important variables in job design include the selection of the conveyance method, the amount
and composition of wellbore fluids, and perforating gun specifics including, shot density, charge
design (big hole/deep penetration) and explosive gram loading.
The gas jet generated by the detonation of the shaped charges ignites the propellant sleeve,
producing a burst of high pressure gas. The pressure of this gas pulse increases until fracturing
(tensile failure) of the formation rock is initiated. The high rate, high pressure turbulent flow of
the mixture of combustion gas and wellbore fluid through each perforation tunnel will extend the
fractures typically 3 - 10 ft (0.91 - 3.0 m) away from the wellbore.
The process can be carried out in overbalance or extreme overbalance conditions to begin injection
or under balance conditions to initiate immediate production to facilitate wellbore cleanup.
The StimGun assembly used in the Mara-Stim process consists of a conventional hollow steel c
arrier perforating gun, a cylindrical sleeve of propellant, sleeve retaining rings and tool centralizers.
The sleeve of propellant is simply slid in place over the gun and secured with the retaining rings.
The sleeve, which is protected by rings and centralizers, consists of versatile and rugged propellant
which has been used in formations from 1,400 - 20,000 ft (427 - 6,096 m) deep, 80°F - 360°F
(27°C - 182°C) 400 - 14,000 psi (2.76 - 96.5 MPa) and in all currently used stimulation fluids. Interval
lengths from 2 - 1,000 ft (0.61 - 305 m) and multiple intervals, (up to 13), have been stimulated in
a single run. The success of the Mara-Stim process is dependent on rigorous pre-job applications/
well assessment, computer modeling, and job design. Post-job interpretation of data and production
results are also very important for the continued success of the technology.
Fast Gauge Data From the StimGun Assembly
The ultra-fast recorder monitors the pressure response of the perforating event and propellant burn.
The data can be compared to a computer model for validation of the model and to estimate rock
properties. In some wells, the fracture gradient can be estimated from this data. One of the most
important uses of the ultra-fast pressure gauge data is to determine proper execution of the job. It
is possible to see the perforating event, the propellant ignition, and the rate and magnitude of the
propellant burn. This data has led to the successful development of the tool and procedures currently
being employed. The ultra-fast recorder has the capability to measure 100,000 data points per second
and can withstand 100,000 g’s of shock load. This recorder, developed specifically for these oil field
applications, came from military technology. Pressure, acceleration, and strain data can all be obtained.
Computer Modeling Enhances Job Design
Job design and post-job analysis are assisted by the PulsFrac™ software. The program is a true dynamic
simulator that models a wide variety of tool, wellbore, fluid, and formation behaviors. By its use, tool
selection is optimized and potential problems may be avoided.
StimGun Assembly
85
86
Pressure Pumping
Equipment
Marine Vessel
Baker Hughes sand control systems is a leader in providing
sand control completions and soft formation completion
technology to the oil and gas industry. Oil company
operators' quest for more efficient completions push the
envelope for high-pressure fracturing and stimulation
services capability and capacity. Our heavy investment
in soft formation sand fracturing research, frac fluid
development and construction of best-in-class stimulation
vessels and oil field skid mounted pumping and blending
equipment, provides the operator with the versatility
required for today's demanding completions.
The fracturing pumping capability complements Baker
Hughes downhole fracturing tool capability. The CK FRAQ ™
tool system with S.M.A.R.T. ™ collet, premium and standard
screen, fluid loss control valves, perforating systems,
accessories and service makes Baker's soft formation
completion systems the preferred choice.
Offshore Fracturing/Stimulation Vessel
The MV RC Baker
87
Pressure Pumping
Equipment
MV RC Baker
Specifications
The MV RC Baker™, DP-1, 224 ft (68.3 m) long by 54 ft (16.5 m)
wide, fracturing and stimulation vessel pioneered 24/7 satellite
communications, for frac pack operations that set a new
standard for offshore fracturing vessel communications.
The RC Baker provides full gel FRAQ PAQ™ service along with
H2O-FRAQ™, H2O-PAQ™, and acid stimulation capability.
224-ft
In standard configuration the RC Baker carries 1,000,000 lb
(453,592 kg) of proppant with 2,500 cu ft (70.8 m3) of proppant
capacity on deck, 8,000 HHP (5,965 kW) and 300 ft (91.4 m) of
3-in. (762-mm) 15,000-psi (103.4-MPa) Coflexip hose providing
the operator with a maximum clean rate of 30 bpm (4.7 m3/min).
The vessel has extra large deck space to place additional pumps,
nitrogen units and equipment.
x 54-ft (68.3-m x 16.5-m) OAL
(2,983-kW) main engines
10 knot speed
Rolling chocks
Dynamically positioned (DP 1)
700-bhp (522-kW) 360° azimuthing bow thruster
Controllable pitch main propellers
Accommodations for 35 personnel
4,000-bhp
R. C. BAKER
FM
88
Pressure Pumping
Equipment
RC Baker Main Deck Specifications
Below Deck Specifications
8,000-HHP
4,000-bbl
(5,965-kW) frac pumps
3 each - SC 2000
1 each - SC 1200 and SC 600
16,800-gal (63.5-m3) Batch Mix
2 each - 200-bbl (31.7-m3) residence tanks
One 300-ft x 3-in. x 15K-psi (91.4-m x 762-mm x 103-Mpa)
Coflexip hose with hydraulic Quick Disconnect
60-bpm (9.5-m3/min) frac blender
60-bpm (9.5-m3/min) chemical add system
50-bpm (7.9-m3/min) continuous mix frac fluid rate
15-bpm (2.4-m3) continuous mix acid rate
6,000-lb (2,721-kg) API hydraulic crane
Full BDAQ monitoring and analysis
Satellite communication - full network 24/7
RDT: Primary satellite with cellular backup
Offshore laboratory facility
Nitrogen capability
(635-m3) fluid capacity below deck
50-bpm (7.9-m3/min) fluid transfer rate to main deck
1,000,000-lb (435,592-kg) proppant capacity
1,000 lb (454 kg) per minute proppant transfer rate
2
2
2
2
80
96"X96"X240"
96"X96"X240"
85
5000 GAL CHEMICAL
TANK
96"X96"X240"
90
5000 GAL CHEMICAL
TANK
5000 GAL CHEMICAL
TANK
95
96"X96"X240"
100
5000 GAL CHEMICAL
TANK
96"X96"X240"
105
5000 GAL CHEMICAL
TANK
CO-FLEX
HOSE &
REEL
75
70
75
60
55
50
45
40
35
200 BBL
200 BBL
RESIDENT TANK
RESIDENT TANK
120"X144"X244"HG 120"X144"X244"HG
89
Pressure Pumping
Equipment
Skid-Based Pumping Equipment
Baker Hughes sand control systems has a world wide fleet of
specially built skid-mounted high pressure pumping equipment
to perform FRAQ PAQ™, H2O-FRAQ™, cased hole gravel packs and
large volume openhole horizontal gravel pack treatments.
Skid-Based Pumping Equipment
90
Compact, skid mounted equipment provides the operator the
flexibility to mobilize the required equipment for each individual
treatment. Skid equipment avoids weather related delays by being
located on the platform and is ready to pump when needed.
Pressure Pumping
Equipment
SC 2000 Triplex Pump
The SC 2000™ triplex pump is a skid mounted pump package
designed to provide the high horsepower needed for fracturing,
stimulation, and high rate gravel pack operations. Each unit
consists of a Detroit Diesel Series 4000™ engine, Allison model
S9800 Power Shift automatic transmission, and SPM model TWS
2250 pump with 4.5-in. (114.3-mm) plungers and delivers
2,000 hydraulic horsepower (1,491 kW). The pump can either be
remotely controlled from the control room or manually operated.
The SC 2000 pump is rated to 15,000 psi (103 MPa) intermittent
service pressure when equipped with 4.5-in. (114.3-mm) plungers.
Overpressure protection is by a pressure sensing circuit that sets
the engine to idle and the transmission to neutral.
Capabilities/Specifications
Max
pressure: 15,000 psi (103 MPa) intermittent service
Hydraulic horsepower: 2,000 hhp (1,491 kW)
Max rate: 12.7 bpm (2.1 m) with 4.5-in. (11.4-cm) plungers
Weight: 53,130 lb (24,100 kg)
Height: 10 ft (3 m)
Width: 8 ft (2.4 m)
Length: 26 ft (8 m)
Summary of Features
Detroit
Diesel Series 4000 engine
model S9800 power shift automatic transmission
SPM model TWS 2250 pump
Allison
91
Pressure Pumping
Equipment
SC 1200 Triplex Pump
The SC 1200™ Hercules triplex pump is a skid-mounted, high
horsepower pump unit designed specifically for fracturing,
stimulation, and high rate gravel pack operations. Although the
unit is designed to pump slurries, it is also capable of pumping
any number of well treating fluids. The unit is capable of being
operated from a remote console up to 100 ft (30.5 m) from the
system. The unit can be split into a pump skid and an engine skid
for ease of handling. Also, for additional weight reduction, the fuel
tank can be removed from the pump skid.
Summary of Features
Detroit
Diesel 12V-149TIB turbo charged, inner cooled engine
model TWS 1800 pump
Equipped with a hydraulic governor, and a Sentinel
shutdown system
Operated either at the console on the unit or by remote
Allison 5 speed automatic transmission
Two-part skid frame
SPM
92
Specifications
Hydraulic
horsepower: Rated 1,300 hhp (224 kW)
Total weight: 60,000 lb (27,273 kg)
Engine half: 32,500 lb (14,773 kg)
Fluid end: 27,500 lb (12,500 kg)
Dimensions: 303 in. L x 100 in. W x 108 in. H
(7.7 m L x 2.54 m W x 2.74 m H)
Pressure Pumping
Equipment
SC 600 Triplex Pump
The SC 600™ triplex pump is a skid-mounted pump unit designed
specifically for gravel pack operations. Although the unit is
designed to pump gravel slurries, it is also capable of pumping any
number of well treating fluids. The standard unit is equipped with
an auxiliary air compressor and two hydraulic circuits for actuating
or supplying power to various auxiliary equipment. This unit can be
split into a pump skid and an engine skid for ease of handling.
Summary of Features
Detroit
8V-92TA turbo-charged, inner cooled engine
with a hydraulic governor, and a sentinel shutdown
system (oil and water)
SPM model TWS 600 pump
Allison 5 speed automatic transmission
Two-part skid frame
Auxiliary air compressor
2 hydraulic circuits: 30 gpm (113.5 L/min) at 1,800 psi
(12.4 MPa) per circuit
Two 12 barrel displacement tanks
Specifications
Hydraulic
horsepower: 425 hhp (317 kW)
Weight: 24,500 lb (11,136 kg)
Length: 84 in. (2.1 m)
Width: 96 in. (2.4 m)
Height: 204 in. (5.2 m)
Max rate: 7 bpm (1.1 m3/min)
Max pressure: 10,000 psi (68.95 MPa)
Equipped
93
94
Fluid Mixing
Model 60 Fraq Blender
The Model 60™ fraq blender is designed to deliver up to
60 barrels per minute (9.65 m3/min) clean water rate during
fracturing operations. The blender is skid mounted and custom
configured to perform the small stages or rapid proppant ramp
pump schedules required by the TSO (Tip Screen Out) fracturing
treatments. The Model 60 blender modifications allow this
blender to be used for soft formation FRAQ PAQ™ (crosslinked gel
carrier fluid frac treatments), H2O-FRAQ's™ (water carrier fluid frac
treatments) and H2O-PAQ's™ (water carrier fluid high-rate gravel
pack treatments).
Specifications
Length:
336 in. (8.5 m)
Width: 96 in. (2.4 m)
Height: 120 in. (3 m)
Weight: 35,000 lb (15,876 kg)
Summary Of Features
Automatic/manual
operation
12-in. (30.5-cm) and one 6-in. (15.2-cm) proppant
delivery augers
100 - 15,000-lb/min (16 - 2,385-m3/min) proppant delivery rate
Variable, automatic blender tub level control
Two accrison dry additive feeders
Two liquid additive pumps
6-in. (15.2-cm) and 3-in. (7.6-cm) mag flow meters each on
suction and discharge
Weather proof operators control console
Two
95
Fluid Mixing
Model 30 Fraq Blender
The Model 30™ BPM fraq blender is a compact skid mounted,
blending package designed to provide versatility in performing
stimulation, fracturing, or frac-pack operations. The compact
blender requires only 200 ft2 (18.6 m2) of area and is easily placed
on rig platforms or vessels where space is limited.
Four individual easily removable proppant silos, allows
700 cft (19.8 m3) of total proppant to be placed within the blender
footprint. Treatments over 700 cft (19.8 m3) may be accomplished
by replacing silos as they empty during the job. A common
54-cft (1.5-m3) hopper positioned within the blender receives
proppant from the silos and transfers it via horizontal augers to
the blender tub.
Using Baker Hughes Intelli-FRAC™ and Intelli-BLEND™ suite of
software the blender can be operated in automatic mode, manual
mode, or a combination of both. These functions include control
of suction rate, proppant feed rate, proppant concentration,
liquid additive, and dry additive rates. The system is capable of
performing ramped or stepped fracturing operations, insuring
the designed slurry properties are achieved. An optional nuclear
densimeter is also available to complement the suite of sensors.
Two auger style dry feeders and two progressive cavity liquid
pumps coupled to coriolis flow meters provide accurate
measurement of chemical additives. An optional liquid additive
module with up to eight additional progressive cavity pumps that
are controlled from the blender console through Intelli-ADD™
software is also available.
All blender rates, totals, volumes, and engine performance data
are accessible from sunlight readable 12-inch displays on the
control console. The onboard computer is capable of exporting
data to external remote displays and data acquisition systems. The
system’s electronics is powered by a 24V deep cycle battery pack.
A backup auto-switching battery charger with universal AC voltage
input can be connected to rig
power to either backup the
engine alternator during jobs
or to charge the battery pack
when not in use.
The complete unit can be
CE Certified.
96
Summary of Features
Intelli-FRAC
software
Detroit Diesel Series 60 engine rated at 525 BHP (392 kW)
Two liquid additive pumps capable of 0.1 to 8.0 gpm
(0.38 to 30.3 L/min)
Two dry additive feeders capable of 0.1 to 12.0 lb/min
(0.16 to 1.91 m3/min)
700 cft (19.8 m3) total proppant storage in four individual,
removable silos
Optional eight additional liquid additive pumps
Max
discharge pressure: (fluid SG 1.0): 90 psi (620 KPa)
Operating slurry rate range: 5-30 BPM (0.79-4.77 m3/min)
Max proppant rate: 10,000 lb/min (1,590 m3/min)
Min proppant rate: 50 lb/min (7.9 m3/min)
Length: 225 in. (5.7 m) (operator platform stowed)
241 in. (6.1 m) (operator platform extended)
Width: 96 in. (2.4 m) (operator platform stowed)
121 in. (3.1 m) (operator platform extended)
Height: 118 in. (3.0 m) (without silos)
236 in. (6.0 m) (with silos)
Weight: 27,000 lb (12,247 kg) (without silos)
113,500 lb (51,483 kg) (with all silos full-2.65 SG prop)
Fluid Mixing
Gravel Infuser
The Gravel Infuser™ is designed to perform low rate water packs
and can be equipped to perform high rate water packs in which
smaller volumes of sand are to be infused. The gravel tank
assembly, which includes a gravel-conveying auger, is fabricated
of stainless steel to reduce corrosion and to prevent gravel
contamination. The gravel-injection auger in the tank assembly
precisely measures gravel feed rates and delivers gravel to the
mixing tub. All wetted components are manufactured of stainless
steel to reduce corrosion from brines, gels, and acid fluids and to
prevent slurry contamination.
Summary of Features
Sand storage tank capacity: 8,000 lb (3,629 kg)
Centrifugal pump equipped with a 35 hp (26.1 kW)
hydraulic motor
Auger powered by a 30-cu in. (491.6-cc) hydraulic motor for low
rates or 19-cu in. (311.3-cc) hydraulic motor for high rates
Specifications
Length: 99 in. (2.5 m)
Height: 107 in. (2.72 m)
Width: 69 in. (1.75 m)
Weight: 7,000 lb (3,175 kg)
Hi-Rate Gravel Infuser
The Hi-Rate Gravel Infuser™ is designed to perform high rate
water packs in which large volumes of sand are to be infused.
The gravel tank assembly, which includes a gravel-conveying
auger, is fabricated of stainless steel to reduce corrosion and
to prevent gravel contamination. The gravel tank is rated for
15,000 lb (6,800 kg) capacity and can be equipped with load
cells for instantaneous gravel-volume and feed-rate data. The
gravelinjection auger in the tank assembly precisely measures
gravel feed rates and delivers gravel to the mixing tub. All
wetted components are manufactured of stainless steel to
reduce corrosion from brines, gels, and acid fluids and to
prevent slurry contamination.
Min rates: 0.5 ppa at 4 bpm (60 kg/m3 at 0.6 m3/min)
Max rates: 4 ppa at 16 bpm (479 kg/m3 at 2.54 m3/min)
Max discharge pressure: 60 psi (0.41 MPa)
Summary of Features
Sand storage tank capacity: 15,000 lb (6,800 kg)
Centrifugal pumped equipped with a 100-hp (74.6-kW) hydraulic
motor that is powered by 2 hydraulic circuits
Auger powered by a 19-cu in. (311.3-cc) hydraulic motor (high
speed low torque)
Charge pumps can be controlled at the Hi-Rate Infuser console
Centrifugal discharge pressure monitored on console
Specifications
Length: 139 in. (3.5 m)
Height: 107 in. (2.72 m)
Width: 71 in. (1.75 m)
Weight: 8,500 lb (3,855 kg)
Min rates: 0.5 ppa at 4 bpm (60 kg/m3 at 0.6 m3/min)
Max rates: 4 ppa at 20 bpm (479 kg/m3 at 3.17 m3/min)
Max discharge pressure: 60 psi (0.414 MPa)
97
Fluid Mixing
Chemical Additive System (CAS Unit)
The CAS Unit (Chemical Additive System) synthesizes polymer
based fracturing fluids that require a short (2–5 minute)
residence time. The CAS unit consists of 1) intake manifold with
a magnetic flow meter, chemical addition manifold, and static
inline mixer; 2) initial mixing chamber with two paddle mixers,
3) secondary hydration chamber and 4) final hydration chamber.
The mixing and hydration chambers provide an 80-barrel (12.7 m3)
residence capacity.
Summary of Features
Manual
or automatic operation
Accufrac™ control software
6 Integrated chemical metering pumps
6 MicroMotion flow meters
Magnetic flow meter for monitoring clean fluid inflow rate and
proportioning polymer concentrate
Static in-line mixer to initiate hydration, followed by paddle
mixers in first hydration chamber
Second and third hydration chambers provide residence time
98
Specifications
Length:
30 ft (9.1 m)
Width: 9 ft (2.7 m)
Height: 15 ft (4.6 m)
Weight: 36,000 lb (16,300 kg)
Hydration capacity: 80 bbl (13 m3)
Fluid Mixing
Twin 13-BBL Batch Mixer
The Twin 13-BBL batch mixer unit is a dual vessel mixing system
designed for batch mixing gelled carrying fluids, sand slurries, or
any other solution used for downhole operations. It consists of
two 13-barrel corrosion resistant plastic tanks, two hydraulic
motor driven mixing mechanisms that are powered to provide
uniform blends of slurries up to 18 ppg (2,157 kg/m3), and stainless
steel mixing paddles. This unit is equipped with a 5-in. x 6-in.
(127-mm x 152.4-mm) Centrifugal pump equipped with Viton®
lining and impeller.
Dimensions/Weight
Specifications
Hydraulic
requirements for optimum mixing performance:
32 gpm at 1,500 psi (121 L/min at 10.3 MPa)
Hydraulic requirements for maximum pump performance:
38 gpm at 1,800 psi (143.8 L/min at 12.4 MPa)
Pneumatic requirements for air actuators: 80 to 100 psi
(552 to 689.5 kPa)
5 x 6 centrifugal pump max rate: 16 bpm (2.5 m3/min)
Discharge pressure: 60 psi (413.7 kPa)
Length:
96 in. (244 cm)
96 in. (244 cm)
Height: 108 in. (274 cm)
Weight with centrifugal: 6,700 lb (3,039 kg)
Width:
Connections
Fill-up
line: 2 in. (2.1 cm)
4 in. (10.2 cm)
Discharge:
99
Fluid Mixing
27-BBL Batch Mixer
The 27-BBL batch mixer unit is designed for batch mixing gelled
carrying fluids, sand slurries, or any other solution used for
downhole operations. It consists of a single 27-barrel (4.28 m3)
corrosion resistant plastic tank, pneumatic valves, and hydraulic
motor driven mixing mechanism that is sufficiently powered to
provide uniform blends of slurries up to 18 ppg (2,157 kg/m3), and
stainless steel mixing paddles. The unit may be equipped with
an optional 5-in. x 6-in. (127-mm x 152.4-mm) Centrifugal pump
equipped with Viton® lining and impeller (Pictured with pump).
Dimensions/Weight
Length:
120 in. (3 m)
96 in. (24.4 cm)
Height: 102 in. (2.6 m)
Weight with pump: 6,700 lb (3,039 kg)
Weight without pump: 6,000 lb (2,722 kg)
Width:
Connections
Fill-up
line: 2 in. (2.1 cm)
line: 4 in. (10.2 cm)
Discharge
100
Specifications
Hydraulic
Hydraulic requirements for maximum pump performance:
Pneumatic requirements for air actuators: 80–100 psi
(552–689.5 kPa)
5-in. x 6-in. (127-mm x 152.4-mm) centrifugal pump max
rate: 16 bpm (2.5 m3/min)
Discharge pressure: 60 psi (414 kPa)
Normal capacity: 27 bbl (4.3 m3)
Absolute capacity: 31 bbl (4.9 m3)
Fluid Mixing
100-BBL Batch Mixer
The 100-BBL batch mixer unit is a mixing system designed for
batch mixing large volumes of gelled carrying fluids, or any other
solution used for downhole operations. It consists of a corrosion
resistant plastic tank, pneumatic valves, hydraulic motor driven
mixing mechanism that is sufficiently powered to provide
uniform blends and stainless steel mixing paddles. This unit is
also equipped with 3-ft (0.91-m) retractable handrails for
operational safety.
Specifications
Hydraulic
(552–689 kPa)
Dimensions/Weight
Length:
101 in. (257 m)
Width: 96 in. (2.44 m)
Height (handrails retracted): 106 in. (2.69 m)
Height (handrails erect): 149 in. (3.78 m)
Weight: 7,500 lb (3,402 kg)
Connections
Fill-up
line: 3 in. (7.62 cm)
4 in. x 6 in. (10.2 cm x 15.2 cm)
Suction:
101
Fluid Mixing
Twin 100-BBL Batch Mixer
The Twin 100-BBL batch mixer unit is a mixing system designed
for batch mixing large volumes of gelled carrying fluids, or any
other solution used for downhole operations. This unit consists
of a partitioned steel epoxy coated corrosion resistant tank,
pneumatic valves, hydraulic motor driven mixing mechanism that
is sufficiently powered to provide uniform blends and stainless
steel mixing paddles. This unit is also equipped with 3-ft (0.9-m)
retractable handrails that enable operators to work safely
while mixing.
Dimensions/Weight
Length:
192 in. (4.9 m)
96 in. (2.4 m)
Height (handrails retracted): 124 in. (3.1 m)
Height (handrails erect): 160 in. (4.1 m)
Weight: 16,000 lb (7,257 kg)
Width:
102
Fill-up
line/manual valve: 3 in. (76.2 mm)
Suction: 4 in. (101.6 mm)
Hydraulic requirements for optimum mixing performance:
(552–689 kPa)
Fluid Filtration
Vertical-Leaf Filtration System
The GFI™ vertical-leaf filtration system combines 400–800 ft2
(37.2 –74.3 m2) of vertical pressure leaf filters, an 18-1/2-bbl
(2.9-m3) DE blender, and a dual-cartridge filter pot into a compact
single skid. All vessels, piping, and internals are made of
corrosion-resistant stainless steel to prevent contamination of the
fluids being filtered. Each cartridge filter pot houses nineteen
40-in. long (1-m), pleated cartridges.
Specifications
Width:
5 ft (1.5 m)
Length: 12 ft (3.7 m)
Height: 9 ft (2.7 m)
Weight: 5,500 lb (2,995 kg)
Summary of Features
Dual-cartridge
filter vessels
40-in. (1-m) cartridges per vessel
18-1/2 bbl (2.9 m3) pre-coat/body-feed blending tank
Pressure/temperature: 100 psi (689 kPa) at 200°F (93°C).
Flow capacity: approx. 1 gpm per ft2 (1.3 m3/min per m2) of filter
media with fresh water
Nineteen
103
Fluid Filtration
Dual Acid Filter
The Dual Acid Filter unit is a skid mounted diluted acid filtering
system. The two vessels can be used either singly or in
combination to filter diluted acids compatible with the pressure
rating and flow rate capacity of the unit. Flow rate capacity is
governed by the size, number and type of filter elements used in
the filter vessels.
Summary of Features
 Vessels
and manifolds constructed of 316L stain-less steel
valves are plastic with a Viton® seat and
 O-rings and stainless steel hardware
 Each filter vessel uses eight 2.62-in. (6.7-cm) OD x 30.00-in.
long (76.2-cm) filter cartridges
 Rated pressure: 125 psi (862 kPa)
 Test pressure: 150 psi (1,034 kPa)
 Butterfly
104
Specifications
 Width:
48 in. (1.2 m)
 Length: 63 in. (1.6 m)
 Height: 56 in. (1.4 m)
 Weight: 1,300 lb (590 kg)
(no fluid in vessel; each vessel will hold 12 gallons (45 L)
Auxiliary Support
Equipment
720 GAL Acid Tank
The 720-Gallon (2.7-m3) acid tank is a U.S. Coast Guard/Department of Transportation approved
vessel used for the transportation of various chemicals. The unit consists of a polyethylene tank
mounted on a stackable skid. Bulkhead fittings and discharge piping are made out exceptionally
corrosion resistant nickel alloy C-276 (e.g., Hastelloy® or equivalent).
Summary of Features
720-gal
(2.7-m3) capacity
Totally enclosed
Transportable
Manufactured and tested as IBC under 49 CFR
3-in. (7.6-cm) female camlock
bottom discharge
Specifications
Length:
8 ft (2.4 m)
Width: 6 ft (1.8 m)
Height: 6.5 ft (2 m)
Weight (empty): 2,400 lb (1,089 kg)
3,000 LB Sand Tote Tank
The 3,000-lb (1,361-kg) sand tote provides a convenient method for transporting gravel pack sand to
the rigsite. This fully-transportable tank is designed to rest above the Gravel Infuser’s™ sand hopper.
The pneumatically operated bottom discharge eliminates the need for cutting sacks during the
pumping operation.
Summary of Features
3,000-lb
(1,361-kg) capacity
Totally enclosed
Transportable
Oil field skid-mounted
6-in. (15.2-cm) bottom discharge
Specifications
Length:
46 in. (1.2 m)
Width: 43 in. (1.1 m)
Height: 71 in. (1.8 m)
Weight (empty): 500 lb (226.8 kg)
Slurry Dehydrator With Diaphragm Pumps
The slurry dehydrator is a skid-mounted tank used to catch gravel pack returns in order to evaluate
gravel-packing efficiency. Sand reversed out is caught by an inner tank liner, measured, and
subtracted from the total sand pumped in order to obtain the volume of sand placed during the
gravel-pack process. The unit is equipped with an air diaphragm pump to transport fluid to the pits.
Summary of Features
Accurate
gravel-placement measurement by
collecting and weighing returned sand
Environmentally safe disposal
Rated return flow rate using water as the
carrier: 4 bpm (0.64m3/min) with
1-1/2 – 2-lb/gal (180 - 240-kg/m3) sand
Sand capacity of 3,000 lb (1,361 kg)
2-in. (50.8-mm) 1502 Fill line
6-in.
(152.4-mm) and 3-in.
(76.2-mm) suction line
3-in. (76.2-mm) discharge line
Specifications
Length:
90 in. (2.3 m)
84 in. (2.1 m)
Height: 108 in. (2.7 m)
Weight: 3,700 lb (1,678 kg)
Width:
105
106
Data Acquisition
Remote Treatment Monitoring (RTM)
RTM rooms are located at Baker Hughes facilities worldwide,
providing our clients with convenient monitoring of offshore
pumping operations. Availability of state-of-the-art fracture
modeling and monitoring software provides the option for the
mini-frac analysis and final job design to be performed in the
same manner, as it would be on-site.
Key to this system is an industry-leading communications
system. Baker Hughes was the first to offer full 24 hours a day,
7 days a week satellite communications from offshore to the
office. Communications on Baker Hughes stimulation vessels are
handled through the on-board PBX and computer network running
Windows NT® operating system. Ship-to-shore communications
for the stimulation is provided by the full-time satellite link.
Backup communications is provided by cellular phone. The
satellite communications are configured with 128K bandwidth.
This configuration provides four phone lines and a full-time
network connection. The phone lines are typically configured
with two voice lines, one fax and one data line; although all four
lines could be used for voice. This configuration was chosen to
provide the most reliable and efficient communication systems
for the vessel. The satellite service provides one primary and one
alternate satellite in different azimuth locations. The alternate
is required to accommodate transmission when the boat is
positioned such that the rig structure blocks the direct path to the
primary satellite.
107
Data Acquisition
BDAQ 9000NT Real-Time Data Acquisition System
The BDAQ 9000NT™ real-time data acquisition system is designed to
monitor and record data during completion and stimulation operations.
The system consists of a portable oil field-ruggedized computer with
a local and remote display, a graphics printer, and an interface for an
external pen plotter. The system can also be housed in a weatherproof, skid-mouted enclosure for offshore operations. The portable
computer provides continuous monitoring and storage for over
50 hours. Up to 20 data variables can be numerically displayed locally
while the remote display can show up to 6 variables, all in realtime. The computer is a PC based Windows NT® operating system,
compatible with MS-DOS® and AutoCAD®. The graphics printer
provides simultaneous real-time, legend-coded graphs of up to
7 data variables with real-time events. The data may also be printed
during the job in tabular form. High-quality, real-time plotting of any
operator-specified time segment is available for real-time analysis of
well completion performance. The data may also be transmitted via
modem or satellite to a remote computer for real-time analysis in the
customer’s office.
Summary of Features
Specifications
Waterproof,
External J-Box
Inputs:
portable system ruggedized, suitable for oil
field and offshore use
Powered from 110 or 220 VAC sources
Sample up to 16 variables while recording and
processing data
Up to 250 calculator channels
English units with metric units optional
Local display data in graphics or digital on screen,
printer or plotter
Remote display parameters selected at pump or
customer’s locale
2-second update and recording
Data stored directly to hard drive
Uninterruptible Power System (UPS), allowing time to
recover from power loss for orderly system shutdown
Real-time and post-job reporting
Full featured playback capability
Custom-generated X-Y plots for detailed real-time or
post-job analysis
Capable of meeting intrinsically safe specifications
3
pressure
turbine flow meters or 60-tooth gear
1 sand feed rate
1 nuclear density gauge
4
Future:
2
turbidity (in and out)
viscosity
2 tank volume indicators
1 temperature
1 sand tank weight sensor
1 bottomhole pressure
1
Control Outputs:
6
analog*
*Up to 13 additional analog and 3 additional digital channels can
be recorded and processed
Display:
Remote
SVGA
Back-Lit
6
LCD
lines x 24 characters at 0.25 in. (6.35 mm)
Power:
110
108
or 220 VAC
Data Acquisition
BDAQ 9000NT Real-Time Data Acquisition System
Specifications (Continued)
Building:
Computer Hardware:
Air
CPU-Pentium®
conditioned
Overhead monitors
Excellent visibility
Weight 7,500 lb (3,401 kg)
10 ft L x 8.5 ft W x 8.5 ft H (3.1 m L x 2.6 m W x 2.6 m H)
Comfortable seating arrangement
Powered by skid generator
Arrangement or rig power (110 Volt)
System Software
Windows
NT® Operating System
BDAQ 9000NT™ data acquisition software
processor 266 MHz
64
Mb RAM
drive: 4.3 Gb
1.44 Mb, 3.5” floppy
32X CD-ROM Drive
I/O, military-style standard
Computer size: 10 in. H x 17.25 in . W x 9 in. D (25 lb)
(.025 m H x 0.438 m W x 0.229 m D, [11.3 kg])
Overall system: 12 in. L x 12 in. W x 18 in. H (70 lb)
(0.305 m L x 0.305 m W x 0.457 m H, [31.8 kg])
Disk
109
Data Acquisition
BDAQ 8000NT Data Acquisition System
The BDAQ 8000NT™ data acquisition system is a portable,
self-contained PC based system running a data acquisition and
logging software package specially designed for use in acidizing
and gravel packing. The unit’s operating system is Windows NT®,
which provides the operator with all the flexibility, functionality,
and portability of an Windows NT workstation. The large 13.8 in.
(35.1 cm) sunlight readable color display provides configurable
real-time readouts in numeric and graphic formats. As the
acquired data is displayed, it is also recorded for post-job analysis
and report generation. The hardware system is field serviceable.
Summary of Features
Computer Hardware
 Data
 Intel®
capacity: 1,500 hours (Max logging speed: 1 Mb per hour)
 Operating temperature: 32°F–122°F (0°C–50°C)
 Power requirements: 100 - 240 VAC at 50 or 60 Hz
 Fuse: 4 amp or equivalent
 Battery backup: provides up to 15 minutes of operation for
power brownouts, and allows enough time for an orderly
system shutdown if total AC power failure occurs.
 Total of 16 transducer inputs (8 analog, 8 frequency)
 32 calculator channels
Specifications
 Length:
20 in. (0.5 m)
 Width: 16 in. (0.4 m)
 Height: 9 in. (0.22 m)
 Weight: 46 lb (20.8 kg)
110
Pentium® processor 200 MHz
 32 Mb RAM
 2.1 Gb hard drive
 8X CD-ROM drive
 1.44 Mb, 3.5” floppy
 13.8-in. color TFT display
 PCMCIA slot
System Software
 Windows
 BDAQ
NT operating system
8000NT data acquisition software
Fraq Paq Fluid Systems
Introduction
Sand control completions require the most advanced fluid
technology, services and procedures. Baker Hughes provides
Best-In-Class stimulation fluids and products world wide to meet
these requirements and to assure maximum well productivity.
Baker Hughes sand control systems extensive staff of fluid
research and technical support personnel are focused on soft
formation sandstone completions. They develop specialized
chemicals, fluid systems and application processes that meet
or exceed the industry and our customer’s sand control
completion requirements.
An ideal fracturing fluid system used in frac pack completions
should have the following characteristics:
to maintain fracture width and transport the proppant
or gravel at reservoir conditions
Predictable performance and the ability to control break time
Compatible with formation mineralogy and reservoir fluids
Good cleanup properties providing maximum fracture and
formation conductivity
Low
fluid leakoff to the formation
must resist shear thinning and provide good friction
reduction properties
Fluid
Viscosity
Baker Hughes sand control systems is an industry leader
in providing frac pack and gravel pack fluid systems. These
systems include complex crosslinked fluid and surfactant
fracturing systems consisting of SurFRAQ™, Diamond FRAQ™,
Emerald FRAQ™, BoraFRAQ™, Ruby FRAQ™; as well as less
complex linear Baker Clean Gel™ “I”, and various brine systems.
Surfactant Frac Pack and Gravel Pack Fluid Systems
SurFRAQ
The SurFRAQ nonionic surfactant charge is ideal for treating sandstone or carbonate
reservoirs in oil and gas wells where minimizing formation damage and maximizing
proppant pack retained permeability is of primary importance. The fluid system
demonstrates superior shale stabilizing characteristics for treating reservoirs with
high shale content.
Comparison of 6% SurFRAQ Systems
600
Viscosity @ 100 sec-1 (cp)
SurFRAQ fluid system is viscous, water based, polymer free, “visco-elastic
surfactant” (VES), hydraulic fracturing, frac pack or gravel packing fluid specifically
developed for Baker Hughes to be used in applications from 80°F–250°F
(26°C–121°C).
500
400
300
200
100
0
100
125
150
175
200
225
250
Temperature (F)
3% KCl
Sea Water 1
1.3 CaCl2
6% SurFRAQ fluid system viscosity in brines
Comparison of SurFRAQ Systems
1000
900
The single additive concentrate can be mixed continuously or batched mixed in
800
700
varying concentrations up to 12% to viscosify seawater and brines made with sodium
600
500
chloride, potassium chloride, calcium chloride, and other brines up to 14.5 ppg
400
300
(1.73°SG). Good viscosity control allows fracturing fluid efficiency adjustments for
200
various applications. Very low concentrations (1.5%–3% by volume) are capable of
100
0
100
125
150
175
200
carrying up to 14 ppa (pounds proppant added) sand to pack the fracture. The fluid is
Temperature (F)
broken by external break materials such as solvents and alcohols and on contact with
1% SurFRAQ
3% SurFRAQ
6% SurFRAQ
10% SurFRAQ
most crude oils to assure post treatment cleanup and will not reform thus minimizing
post treatment cleanup problems.
Apparent viscosity vs. temp 3% KCl
225
250
111
Diamond FRAQ
Features/Benefits
Diamond FRAQ™ fluid system is a water-based non-ionic
“visco-elastic surfactant” (VES) fluid designed for treating oil and dry
gas sandstone reservoirs where minimizing formation damage and
maximizing proppant and gravel pack gravel retained permeability
is of primary importance. Baker Hughes specifically developed
the visco-elastic surfactant concentrate and the internal breaker
system for sandstone frac pack applications where high retained
permeability of the proppant in the perforation tunnels and casing screen annulus is required.
Diamond
FRAQ fluid incorporates unique internal BreakBAQ
chemistry to break the VES viscosity using bioactive agents
and catalysts
The internal breakers work in all reservoirs including in dry gas,
condensate and oil reservoirs
The fluid can be broken by both internal and external breaker
systems assuring post treatment cleanup
Does not degrade with time except with the use of internal
breakers and upon contact with hydrocarbon fluids
Excellent retained permeability of 90%–99% to maximize
productivity and minimize draw down
The fluid provides excellent sand/proppant transport
characteristics. Concentrations of 1.5%–3% by volume are
capable of carrying up to 14 ppa (pounds proppant added) sand
to pack the fracture
Leak off characteristic facilitates packing of the casing–screen
annulus for the gravel pack operation
The broken Diamond FRAQ fluid will not reform, minimizing
post treatment cleanup problems
The Diamond FRAQ fluid flows back with low differential
pressure to recover treating fluid
The non-ionic Diamond FRAQ surfactant is insensitive to
emulsion formation in most crude oils
The Diamond FRAQ fluid has demonstrated superior shale
stabilizing characteristics for treating reservoirs with high
shale content
Wide temperature range, 80°F–250°F (26°C–121°C) to treat
most formations
Diamond FRAQ’s VES surfactant can be broken with internal
breakers or external breakers. The internal breaker system utilizes
Baker Hughes unique BreakBAQ™ chemistry consisting of bioactive
agents and catalysts to break the VES viscosity and is pumped
with the main frac fluid. The concentrations of these additives are
adjusted to reservoir conditions and treatment requirements to
degrade the visco-elastic surfactant with time and concentration
across its temperature range. The external breakers are hydrocarbon
based fluids pumped ahead or behind the Diamond FRAQ fluid or by
the oil in the reservoir.
The system is ideal for use in both gas and oil sandstone reservoirs
as it retains the natural water wet condition of the reservoir rock
unlike other cationic VES systems that tend to oil wet sandstones
which are undesirable for high rate production of hydrocarbon fluids.
Diamond FRAQ concentrate is a single additive concentrate that
forms a non-ionic micelle viscous solution when added to aqueous
fluids. The VES surfactant will viscosify seawater and brines made
with sodium chloride, potassium chloride, calcium chloride and
most bromide brine blends to 14.5 ppg (1.73°SG). Fluid viscosity
is controlled by the concentration of the Diamond FRAQ VES
concentrate and base brine. Diamond FRAQ is suited for use in a
variety of frac pack and gravel pack applications up to 250°F (121°C).
Diamond FRAQ Fluid Break
600
500
400
300
200
100
0
100
125
150
175
200
225
Temperature (F)
3% KCl
Sea Water 1
1.3 CaCl2
Diamond FRAQ Recommended Concentrations
Recommended % VES Concentration vs. Temperature °F (°C)
112
Temperature
125
(51.7)
150
(65.6)
175
(79.4)
200
(93.3)
225
(102.2)
250
(121.1)
% VES
2
3
4
5
6
10
250
Crosslinked Frac Pack And Gravel Pack Fluid Systems
BoraFRAQ Systems
BoraFRAQ™ is a series of crosslinked fracturing fluid system especially designed for frac pack
completions. This system consists of a high quality, low solids polymer crosslinked with a borate
crosslinker package. The BoraFRAQ system can be used over a wide range of reservoir condition
requirement and can be applied at bottomhole temperatures of 70°F–300°F (21°C–150°C). It is
compatible with fresh water, potassium chloride (0-10% by weight), sodium chloride (0-8% by
weight) and seawater.
The BoraFRAQ system provides the option of a non-delayed or a delayed crosslinker to minimize the
effect of friction pressure during the frac pack completion.
Controlled break time can be built into the BoraFRAQ system using the breakers researched and
developed by Baker Hughes fluids R&D technology laboratory.
BoraFRAQ Recommended Polymer Loading vs Temperature
Temperature
(lb/1,000 gal)
kg/m3
25
3.0
70 - 180
21 - 82
30
3.6
120 - 275
49 -135
35
4.2
180 - 310
82 -154
40
4.8
200 - 350
93 - 177
°F
°C
Emerald FRAQ
Emerald FRAQ™ is a first generation “green” frac pack and
fracturing fluid that is formulated with a low residue guar
polymer, crosslinked with borate ions, specifically designed
to provide an oil and grease content of <29 mg/l Hexane
Extractable Material (HEM). The polymer slurry of Emerald
FRAQ and other components are formulated at the point
of blending to have <29 mg/l.* The polymer is used in
Features/Benefits
Emerald FRAQ Base Gel Viscosity
45
Emerald
Cent Poise
FRAQ is a first generation
“green” fracturing fluid with the
following characteristics:
Emerald FRAQ is formulated to have <29 mg/l
HEM at the point of blending
Good shear stability to minimize degradation
when pumped through the workstring and
gravel pack tools
Emerald FRAQ is a high pH crosslink fluid
concentrations from 25–50 lb/1,000 gal (3–6 kg/m3) depending
on formation temperature, permeability, and
desired pump time. Lowering the polymer loading along
with the low residue polymer minimizes damage to the
formation and the proppant bed. Crosslink time can be varied
from surface by as much as 10 minutes depending on well
treatment requirements.
25 lb/Mgal
40
30 lb/Mgal
35
35 lb/Mgal
40 lb/Mgal
30
25
20
15
20
70
75
80
85
90
95
100
Temperature (F)
*Oil and grease from external sources such as lubricating oil, grease, and pipe dope will increase the oil and grease content of Emerald FRAQ.
Emerald FRAQ is formulated to be oil and grease free by definition of < 29 mg/l of hexane extractable material. It must be formulated only with approved additives listed in the mixingmanual. Substitution or addition of
additives not listed in the mixing manual is strictly forbidden without written permission from the Manager of Baker Hughes Fluids Research andDevelopment Center in Houston, Texas, and automatically VOIDS any and all
warranties, express or implied, including warranties of fitness for particular purpose and merchantabilityunder applicable law or under the terms of sale of Baker Hughes.
113
Fluid
demonstrates pseudo perfect proppant transport with
excellent proppant support in pH ranges above 9.5
Applicable in reservoir temperatures in excess of 300°F (150°C)
Emerald FRAQ™ can be formulated with a combination of
soluble and encapsulated breakers. This allows proper gel
breaks to be achieved in the proppant bed, gel filter cake, and in
the reservoir matrix
Emerald FRAQ-30 ppt Friction Pressures
Friction Pressure (psi/1,000 ft.)
1,000
100
10
Emerald FRAQ fracturing fluid has the following advantages:
1
10
High
fluid efficiency allowing fracture geometry to be achieved
in high kH intervals
Compatible with normal additive packages
Relatively high retained reservoir matrix permeability ranging
from 80%–50%, while the proppant pack is 50% or more
BreakBAQ, Baker Hughes new generation breaker technology
helps to minimize gel damage to maximize conductivity
Emerald FRAQ achieves large pumping fracture widths,
which allows placement of high proppant concentrations
to maximize the closed fracture width, resulting in greater
fracture conductivity
Low pumping friction properties can be achieved by optimizing
crosslink time. This will save hydraulic horsepower, reduce
wellhead pressures, and allow treatments at higher rates
Fluid Type
114
Temp
100
Rate (bpm)
2-3/8” 4.7 ppf
2-7/8” 8.6 ppf
3-1/2” 15.8 ppf
5” 19.5 ppf
190F Emerald FRAQ 30
Viscosity at 100 sec-1 (cp)
500
400
300
200
100
0
0
30
60
90
120
Time (min)
0.5 gal/Mgal
GBW-174L
No Breaker
GBW324
DBW-1
1.0 gal/Mgal
GBW-174L
Shut-In
kair
ki
kf
lb/Mgal
kg/m3
hrs
mD
mD
mD
0.015
2.0
0.24
13
1,000
856
495
58
-
2.0
0.24
33
800
79
62
77
-
0.5
0.06
34
800
106
55
52
°F
°C
lb/Mgal
kg/m3
Emerald FRAQ 25
150
65.5
0.125
Emerald FRAQ 30
175
79.4
-
Emerald FRAQ 35
200
93.3
-
% Return
Perm
Ruby FRAQ
2,500
Ruby FRAQ is a high temperature, high pH fracturing fluid
that uses a low residue derivatized hydroxypropyl guar (HPG)
polymer, crosslinked with zirconate ions. The fluid is designed
for higher temperature fracture stimulation and frac pack
applications of 250°F–>350°F (120°C–180°C). The polymer is
used in concentrations from 30–60 lb/1,000 gallons depending
on formation temperature, permeability and pump time. Crosslink
time can be varied from instant to greater than 10 minutes
depending on well treatment requirements. The chemicals used to
formulate Rudy FRAQ are oil and grease free and do not contain
any priority pollutants.
™
Apparent Viscosity (cp)
2,000
1,500
1,000
500
0
0
60
120
180
240
300
306
Time (min)
511/sec
Properties
170/sec
100/sec
40/sec
The fluid system incorporates either a surface crosslinker or
delayed crosslinkers to minimize shear degradation when
pumped through the work string and gravel pack tools
Ruby FRAQ is a high pH crosslink fluid, crosslinking at a pH > 9.5
Zirconate crosslinkers are used to provide high temperature fluid
stability and provide the desired x’ link time
Fluid demonstrates pseudo perfect proppant transport and
excellent proppant support in pH ranges above 9.5
Applicable in reservoir temperatures > 350°F (180°C)
Ruby FRAQ can be formulated with a combination of soluble
and encapsulated breakers. This allows proper gel breaks to be
achieved in the proppant bed and gel filter cake as well as the
reservoir matrix permeability
Features/Benefits
High temperature viscosity stability
Ruby FRAQ has good to excellent fluid efficiency allowing
fracture geometry to be achieved in high kH intervals
Ruby FRAQ has generated regain on permeability > 50 md on
Berea core
Viscosity in 100’s of cps at high bottom hole static temperatures
Predictable performance enables a controlled break time that
allows optimization of pump time, well clean up, and minimizes
damage to the formation and proppant permeability
Compatible with normal additive packages
Regain Permeability Versus Throughput
Net confirming stress: 1,500 psi (10.3 MPa)
Fracture fluid: Ruby 60#
Baker Hughes
Berea core plug
Fracture fluid evaluation study
File: HOU-030125
Temperature: 300°F (149°C)
Overbalance: 500 psi (3.45 MPa)
Sample number:
Sample depth, meters:
Permeability to air, md:
*Porosity, fraction:
4
0.176
100.0
90.0
80.0
Apparent Viscosity (cp)
70.0
60.0
50.0
40.0
Circulated Fracture Fluid for 30 minutes at
500 psi Overbalance and Lock-in for 2
30.0
20.0
10.0
0.0
0
10
20
30
40
50
60
Cumulative Fluid Injected, pore volumes
Before Fracture Fluid Circulation
After Fracture Fluid Circulation
115
116
Gravel and Proppants
Fracturing Proppants and Sand Control Gravel
The choice of gravel and/or proppant can determine a successful
sand control completion or a failure. Baker Hughes provides a high
quality silica sand and fracturing proppant that meets or exceeds the
standards recommended and adopted by the American Petroleum
Institute (API) for sand control gravel API-RP58, fracturing proppant in
API-RP56 and high strength proppant under API-RP60.
Baker Low Fine Gravel
Baker Low Fine™ gravel is a high quality, non-fractured, well-rounded
silica sand designed specifically for sand control applications. The
outstanding quality of this gravel packing and frac packing medium
results in a high quality sand control pack with excellent permeability
and conductivity.
Baker Low Fine gravel is available from stock in mesh sizes of 20/40,
40/60, and 50/70. Other sizes that may be obtained by special order
are 12/20, 16/30, 20/30, 30/40, 40/50, and 50/60 U.S. mesh.
Baker Low Fine gravel may be applied in gravel packing or frac
packing at closure stresses up to 4,000 psi (27.6 Mpa). At closures
higher than 4,000 psi (27.6 Mpa), resin coated silica sand or ceramic
gravel or proppant should be considered.
Ceramic Gravel or Proppant
Product Family Nos. H49211, H49212, H49214, and H49225
Ceramic gravel or proppant is a manufactured material. It is
available as a low specific gravity, an intermediate strength
and a high strength gravel or proppant. This material is well
rounded and can be applied over a wide range at closure stresses
(exceeding 15,000 psi [103.4 Mpa])
Resin Coated Gravel or Proppant
Resin coated gravel packing or frac packing material can be
provided with the same high quality Baker Low Fine gravel or
ceramic base material. Resin coating of sand allows the sand
to be utilized at closure stresses up to 8,000 psi (55.2 Mpa).
Resin coating can be applied as a precured coating or a curable
coating. The resin in the precured state gives more strength to
the gravel particle, while the resin as a curable coat gives the
particle more strength and allows the particles to form a solid
high permeable structure controlling the flowback of gravel and
formation fines.
Gravel or Proppant Description
Sand
•
•
•
•
Used at closure stresses up to 4,000 psi (27.6 Mpa)
Inexpensive
Compatible with most completion fluids
Can be resin coated to improve performance and
control flowback
Ceramics
• Available in three different densityclassifications
that cover a closure stress range up to 15,000 psi
(103.4 Mpa) plus
• Compatible with most completion fluids
• Can be resin coated to improve performance and
control flowback
• More uniform than sand and has a high degree
of roundness
Resin Coated Gravel or Proppant:
• Sand and ceramic gravel and/or proppants can be
resin coated to improve performance of the product
and control flowback of the material
• Resin coating of sand can extend its closure stress
range up to 8,000 psi (55.2 Mpa)
• Resin coatings may affect the performance of some
completion fluids
• Contains gravel and proppant fines that may be
present due to normal crushing that occurs as
closure takes places
117
118
Acid Systems
Acid Systems
Acid systems can be designed from a number of different
acids and/or acid blends to prepare your well for a sand
control completion. Acids or acid blends are used to remove
permeability damaging material from the completion string and
to remove near wellbore formation damage caused by drilling
or workover procedures. Commonly used acids available are
mineral acids (hydrochloric and hydrofluoric) and organic acids
(acetic and formic).
Hydrochloric Acid
Hydrochloric acid is effective in removing carbonate type scales
and iron deposits.
Hydrofluoric Acid
Hydrofluoric acid blends such as hydrochloric/hydro-fluoric and
organic/hydrofluoric effectively dissolves silica, silicates, clays
and formation damage in sandstone formations.
Organic Acids
Organic acids (primarily acetic, and formic acid) are applied in
high temperature wells for their low corrosive characteristics and
their ability to be easily inhibited. They are effective in removing
carbonate and iron type scale. Organic acids are primarily used in
wells where long pipe contact time may occur, and where chrome,
or aluminum pipe or tools may be present.
HTO Acid
HTO™ acid is a patented organic acid system, targeted for high
temperature applications. It is also biodegradable with very low
toxicity. Corrosion rate tests show that at 350°F (177°C) the
corrosion rate of 10% HTO acid is 0.001 lb/ft2 on 22Cr for
16 hours. The acid systems is suitable for carbonate or sandstone
matrix acidizing and in various clean up applications, either alone
or as a hydrofluoric acid system. The recommended application
concentration is a 10% solution, and is compatible with most
conventional acidizing additives.
The temperature range for sandstone acidizing is from 150°F
(66°C) to 400+°F (204+°C). In carbonate acidizing, the temperature
should be above 150°F (66°C), however it has applications at
lower temperatures. The HTO Acid system chemical reaction
rate is between that of formic acid and acetic acid systems at
high temperatures and shows all the desirable features of high
reactivity and low corrosiveness.
34 fl oz (1,000 mL) acid flow test through sand pack on stainless steel screen at 250°F (121°C)
10% Acetic + 5% NH4CL + 2% CI-105
10% Acetic + 5% NH4CL + 2% CI-105
10% HTO + 5% NH4CL + 2% CI-105
119
Acid Systems
Typical Acid Systems
Acid blend: hydrochloric, hydrofluoric and/or organic acids or
blends of each
Corrosion inhibitor: based on type of acid, temperature, contact
time and type of pipe
Iron control additives: to prevent the precipitation of iron
Mutual solvents: in special occasions, a solvent package may be
required to make the formation more receptive to acid treatment
Surfactant package: non-emulsifier and surface tension agents.
Based on fluid compatibility (treating fluids and reservoir fluids),
gas and/or oil well and formation mineralogy
Dissolving Power per 1,000 gallons of acid
Acid
Calcium Carbonate Dissolved
28% HCl
3,650 lb (1,656 kg)
15% HCl
1,850 lb (839 kg)
10% HCl
1,200 lb (544 kg)
10% Acetic
700 lb (318 kg)
10% Formic
930 lb (422 kg)
Dolomite Dissolved
15% HCl
1,700 lb (771 kg)
Sand Dissolved
3% HF
202 lb (92 kg)
Silicates (Feldspars or Clays) Dissolved
3% HF
316 lb (143 kg)
Smectite Clay Dissolved
3% HF
120
173 lb (79 kg)
Chemical Additives
Chemicals for Acid and Fracturing Fluid Systems
Baker Hughes has a complete line of chemicals to compliment
and assist the recovery and enhance performance of the well.
Acid Corrosion Inhibitors
Acid blends are very corrosive to metals; therefore, a corrosion
inhibitor must be included in every acid system. Baker Hughes
provides acid corrosion inhibitors for every type of acid blend and
for a wide range of temperatures.
CI-100
Corrosion inhibitor for inorganic acid (hydrochloric and
hydrochloric/hydrofluoric blends). Economically priced corrosion
inhibitor for use in moderate to high temperature wells. At
temperatures above 225°F (107°C) intensifiers may be required
in conjunction with CI-100. Effective in steel and chrome pipe.
Concentrations range from 1.5–12 gal per 1,000 gal
(1.5–12 L/cu m) of acid.
Corrosion Inhibitor Intensifiers
CI-105
A corrosion inhibitor for organic acid systems that can be used in
hydrocarbon wells with moderate to high temperatures. Corrosion
inhibitor intensifiers are only required at temperatures above
250°F (121°C) when pump-time is greater than six hours. The
presence of mutual solvents and/or surface acting agents has
little effect on the performance of CI-105. Concentrations range
from 2–10 gal per 1,000 gal (2–10 L/cu m) of acid.
Acid intensifiers used in conjunction with acid corrosion inhibitors
perform synergistically with the inhibitor to enhance the
effectiveness of the corrosion inhibitors at elevated temperatures.
CI-200
Corrosion inhibitor for inorganic acid (hydrochloric and
hydrochloric/hydrofluoric blends) used in low (70°F/[21°C]) to
moderate temperature (225°F/[107°C]) wells. At temperatures
above 225°F (107°C), intensifiers may be required in conjunction
with CI-200. CI-200 is specifically formulated so that there are no
aromatic solvents, alkyl phenols or quaternaries, and heavy metal
present. Concentrations range from 2–15 gal per 1,000 gal
(2–15 L/cu m) of acid.
CII-101
An organic acid that performs as an intensifier. This intensifier
does not synergistically enhance the corrosive protection of the
inhibitor; however, its presence within the acid system improves
the performance of most acid inhibitors up 350°F (177°C). Normal
concentrations range from 25–100 gal per 1,000 gal
(25–100 L/cu m) of acid.
CII-107
An iodide compound used as an intensifier. This intensifier does
perform synergistically to enhance the effect of the corrosion
inhibitor. Normal range of use is 8–50 lb per 1,000 gal
(1 kg–6 kg/cu m) of acid.
121
Chemical Additives
Surfactants (Surface Acting Agents)
Surfactants or surface acting agents when added to fluid systems, act
to lower the surface tension between liquids and liquids, liquids and
gases, and liquids and solids. They may perform as water wetting
agents or oil wetting agents. They are classified as anionic, cationic,
nonionic or amphoteric. Surfactants are used to prevent the formation
of stable emulsion between well fluids and treating fluid. Surfactants
are also used to enhance the recovery of treatment fluids from the
matrix of a formation and/or sand control gravel/proppant.
NE-110
A nonionic non-emulsifier used in fracturing systems to prevent the
formation of stable emulsions with most crude oils. NE-110 has
been found to be an excellent non-emulsifier for polymer laden fluids
when mixed with crude oils. The concentration to be used should
be determined by compatibility test with the formation crude oil.
However, the recommended concentration for use ranges from 0.1 to
0.2% by volume of fracturing fluids.
NE-120
A nonionic surfactant which is a very effective matrix acidizing
non-emulsifier. Prevents the formation of stable acid/oil emulsions
for most crudes up to 380°F (193°C). NE-120 may be used in acetic,
formic, hydrochloric, or hydrochloric - hydrofluoric acid systems. It can
be used in both sandstone and carbonate reservoirs, and is compatible
with amphoteric, cationic and anionic additives. NE-120 is a amber
nonionic surfactant that can be applied in a wide range of fluids
including brines, fracturing fluids, and acids to prevent emulsions in
most oil wells. Recommended concentration for use ranges from 0.1
to 0.5% by volume in brines, acids, and fracturing fluids.
ST-100
A nonionic gas well surface acting agent that is very effective as a
surface tension reducer and foamer in brines and acids, which aids
in cleanup of wells with low bottomhole pressure. The addition of
ST-100 improves the penetration of stimulation treatments, and
the recover of workover fluids and load water in gas wells. ST-100
is effective at reducing surface tension in most acid systems and
fracturing fluids up to temperatures of 300°F (149°C). It can be
used in both sandstone and carbonate reservoirs. It is compatible
with amphoteric, cationic and anionic additives. Recommended
concentration for use ranges from 0.1 to 0.5% by volume in brines,
acids, and fracturing fluids.
122
NE-100
ST-101
A nonionic surfactant which is a very effective in fracturing fluid
and acid systems as a non-emulsifier. Prevents the formation of
stable emulsions in most crudes up to 380°F (193°C). The addition
of NE-100 increases the effectiveness of stimulation and workover
fluids, and helps eliminate formation damage due to emulsion blocks.
It can be used in both sandstone and carbonate reservoirs, and is
compatible with amphoteric, cationic and anionic additives. NE-100
is a clear nonionic surfactant that can be applied in a wide range of
fluids including brines and acids to prevent emulsions in most crude
and condensate wells. Recommended concentration for use ranges
from 0.1 to 0.7% by volume in brines, acids, and fracturing fluids.
A nonionic oil well surface acting agent which is very effective in
reducing surface tension in water-base fluids, brines and acids. The
addition of ST-101 leads to increased penetration of stimulation
treatments and the recover of workover fluids. ST-101 is effective at
reducing surface tension in most acid systems up to temperatures of
225°F (107°C). It can be used in both sandstone and carbonate. It may
be used in wells with low bottomhole temperatures and low gravity
crudes to prevent damage in the near wellbore region from fracturing
and acid treatments. Recommended concentration for use ranges
from 0.2–0.5% by volume in brines, acids, and fracturing fluids.
Chemical Additives
Iron Control Agents
During an acid treatment, iron from the tubing and the formation can
be dissolved into solution as ferric iron. This iron can hydrolyze and
precipitate as the acid spends and the pH increases above 2. Using
an effective iron control agent can prevent the precipitation of iron.
Iron control agents used to inhibit the precipitation of iron from
spent acid are pH control agents (acetic acid, etc.), chelating or
sequestering agents, and reducing agents.
Iron Control Agents
Agent
Chelation Ratio(lb chelator/lb of iron)
Amount to Treat 1000 ppm Fe+3 in Solution
Solubility in 15% HCl
FE-120 (chelator)
3.53:1
29.45 lb/Mgal (3.53 kg/cu m)
>300 lb/Mgal (>35.95 kg/cu m)
FE-120L (chelator)
3.53:1
5.89 gal/Mgal (5.89 L/cu m)
60 gal/Mgal (60 L/cu m)
FE-123 (chelator)
3.61:1
30.1 lb/Mgal (3.61 kg/cu m)
Very Soluble
FE-125L (chelator)
3.61:1
12.29 gal/Mgal (12.29 L/cu m)
Very Soluble
FE-400 (reducing agent)
1.56:1
6.8 lb/Mgal (0.81 kg/cu m)
Very Soluble
FE-120
FE-125L
A citric acid performs as a chelator to complex iron in solution
to prevent the precipitation of iron. FE-120 is inexpensive and
can be used in a wide variety of acid systems. At concentrations
greater than 14 lb per 1,000 gallons (1.68 kg/cu m) and in the
presence of dissolved calcium and the lack of complexable
iron, a portion of the FE-120 may precipitate as calcium
citrate. Complexes ferric iron to prevent the formation of ferric
hydroxide, a gelatinous precipitate formed when the pH of spent
acid increases to above 2. FE-120 can effectively be used at
temperatures up to 200°F (93°C).
The ammonium salt of nitrilotriacetic acid (NTA). A 33%
solution of the NTA salt providing 2.45 pounds of NTA acid
equivalent per gal (0.29 kg/L). FE-125L is tolerant of calcium
found in heavy brines or formation rocks, and is also compatible
with hydrofluoric, formic and acetic acid solutions. FE-125L will
complex ferric iron and prevent the formation of ferric
hydroxide, a gelatinous precipitate formed when the pH of
spent acid increases to above 2. Stable at temperatures up to
350°F (177°C). FE-125L is an effective chelator at 200°F (93°C)
and up to a pH of 5.
FE-120L
FE-400
A liquid citric acid performing the same as FE-120 chelating iron
to prevent it from precipitating as the pH increases above 2.
FE-120L contains 5 lb FE-120 per gallon (0.6 kg/L).
A reducing agent that converts ferric iron to ferrous iron. Ferrous
iron is more soluble than ferric iron. The ferric ion begins to
precipitate at pH 2. The ferrous ion remains in solution at pH
as high as 7– 8. FE-400 used in conjunction with iron chelating
agents can enhance the performance of those agents. FE-400 is
effective up to 300°F (149°C). The normal usage range is
2–20 lb per 1,000 gal (0.24 kg–2.4 kg/cu m).
FE-123
Nitrilotriacetic acid can be used in inorganic acid systems
where the sodium ion is undesirable. FE-123 complexes ferric
iron and prevents the formation of ferric hydroxide, a gelatinous
precipitate formed when the pH of spent acid increases to above
2. FE-123 has minimal solubility in organic acid systems. FE-123
is stable at extreme temperatures, 300°F (149°C) plus, and is an
effective chelator up to 200°F (93°C) at a pH range up to 5.
123
Chemical Additives
Mutual Solvents
MS-100
A very effective water wetting organic solvent that improves the
performance of acid stimulation treatments. Eliminates water
blocks and improves the relative permeability of the formation to
oil and gas. May be applied up to temperatures of 300°F (149°C).
The recommended concentration to use is 5% by volume in brines
or acids.
Mutual solvents are soluble in both oil and water. They are one
of the most important additives that can be incorporated into the
acid system. Mutual solvents improve the solubility of corrosion
inhibitors into the acid system, reduce residual water saturation
from spent acid following treatment, and aid in gas well clean-up.
Mutual solvents water-wet fines and prevents the development of
stable emulsions. They can disperse and/or suspend fines to assist
in clean up after treatment. Mutual solvents aid in maintaining the
formation in a water-wet condition.
MS 77
A proprietary blend of specialty additives and solvents designed
for use in acid for the removal of water blocks near the face of the
wellbore in oil wells. It is also an excellent mutual solvent for gas
wells. MS-77 penetrates and breaks down water blocks or paraffin
deposits that may block pore space. Acid solutions containing
MS-77 will also break emulsions and disperse solids, which
leaves the formation in a water-wet state, facilitating increased
productivity of the reservoir. MS-77 is soluble in both oil and
water. Typical dosages are from 5–10% by volume.
MS-90
An ethylene glycol monobutyl ether, EGMB is soluble in both oil
and water. MS-90 will enhance the overall performance of other
surfactants. MS-90 is effective in removing water blocks and
preventing the formation of stable emulsions by water wetting
fines. It will leave the formation water-wet, maintaining or
providing an excellent relative permeability for oil production.
Typical dosages are from 5–10% by volume.
124
Acid Gelling Agents
Gelling agents are used in acid systems to retard the acid reaction
rate and as a friction reducer. By retarding the acid system,
deeper penetration of the acid can occur before the acid is spent.
Reduction in friction pressure allows the acid to be injected at
fracturing rate without losing treating pressure to pipe friction.
AG-193
A cationic emulsion polymer formulated to viscosify all
concentrations of hydrochloric (HCl) acid. The recommended
loading is 5–15% by volume. The recommended concentration
depends on the viscosity desired, and the temperature at which
it is to be used. AG-193 loadings should be determined from
laboratory evaluations. AG-193 is also an excellent friction reducer
for acids and brines at lower concentration. The recommended
loading for use as a friction reducer is 0.05– 0.1% by volume.
AG-193 is compatible with most brines, but should be evaluated
prior to using.
Chemical Additives
In any type of drilling, completion or well workover, chemicals are
needed to protect the formation mineralogy, assist in the recovery
of fluids foreign to the well and maintain the well’s production at its
maximum. Baker Hughes laboratory has researched and developed
a line of products for use in completion fluid systems to minimize
damage to the formation, and gravel or proppant pack.
Scale Inhibitors
Scale is a solid precipitate that occurs when the chemical
equilibrium in the reservoir is changed. Every time a well is
drilled, completed, or produced, the equilibrium state can be
altered. Therefore, there is a potential for scale deposition to
occur. Scale deposition can occur during well completion when
Clay Stabilizers
two incompatible waters such as completion brines and formation
water, seawater and formation water, etc., become blended
A great many of the sandstone formations contain some type
together. Scale deposition can also occur during the production of
of clay within its matrix and when a foreign fluid such as a
a well. As the temperature and the pressure decreases during the
completion fluid is introduced into the formation there is a
production of a well the higher the potential for scale deposition
potential for damage to those clays. Salts such as potassium
to occur. The most common scales found in the oil industry are
chloride (KCl), ammonium chloride (NH4Cl) and sodium chloride
iron, chloride, carbonate, sulfate, silica and hydroxide.
(NaCl) are used in water-base systems to protect the formation
Baker Hughes provides scale inhibitors to help prevent or
clays. However, in most cases, a salt solution alone cannot provide
minimize scale deposition.
the protection that is needed. Therefore, a chemical clay stabilizer
is needed.
SI-203
CS-7
A weak cationic clay stabilizer used in water base fracturing
systems in combination with salts such as potassium chloride,
and ammonium chloride and seawater. The required concentration
depends on the amount and type of clays present. Recommended
dosage is 1.0–3.0 gal per 1,000 gal (1.0–3.0 L/cu m). While CS-7 is
compatible with most fracturing fluid additives, verification tests
are recommended.
CSC-6
A cationic clay stabilizing agent capable of stabilizing clays
which can be mobilized or activated during gravel packing, frac
packing or acidizing. The recommended addition concentration
for acid treatment post flush is 2.0–10.0 gal per 1,000 gal
(2.0–10.0 L/cu m). For gravel packing or frac packing completions
the recommended concentration is 2.0–5.0 gal per 1,000 gal
(2.0 – 5.0 L/cu m). While CSC-6 is compatible with most additives,
verification tests are recommended.
Highly effective scale control inhibitor for barium sulfate, calcium
sulfate and calcium carbonate scales. SI-203 is anionic and can
be used in completion brines, having excellent solubility and scale
control properties. SI-203 is ideal for use in fracturing or gravel
packing systems prepared with seawater. The recommended
dosage varies from 0.5–2 gal per 1,000 gal (0.5–2 L/cu m). In
seawater base systems and with monovalent completion brines
(i.e., NaCl, KCl), use SI-203 at concentrations of 0.5–1.0 gal per
1,000 gal (0.5–1.0 L/cu m). In high salinity divalent brines
1.0–2.0 gal per 1,000 gal (1.0–2.0 L/cu m) is recommended. SI-203
is applicable at temperatures up to 300°F (149°C).
SI-352
A multi-purpose chemical formulated to be an effective watersoluble scale inhibitor and corrosion inhibitor as well as an oxygen
scavenger. The recommended concentration ranges from 1.5 ppm
(0.00015%) as scale inhibitor to 100 ppm (0.01%) as a corrosion
inhibitor for completion brines. SI-352 contains a red dye for
tagging fluids to indicate that fluid has been treated.
125
Chemical Additives
Biocides
Bacteria growth in the oil industry can be a problem. Both aerobic
and anaerobic bacteria can be found present in drilling fluids,
and completion fluids. The problem causing bacteria normally
encountered in the oil industry are sulfate reducing bacteria (SRB),
slime forming bacteria, and iron bacteria. Fluids that contain
polymers (such as linear gels, fracturing gels, and drilling fluids), are
excellent breeding grounds for bacteria. The presence of aerobic
bacteria in these polymer systems can negate the performance of
that fluid system, and/or introduce reservoir-damaging bacteria
into the well. Once bacteria have been introduced into the well
environment, a colony of bacteria can adapt themselves to the
condition of the well and/or reservoir and possibly spread to
adjoining wells. However, this can be prevented by treating
fluids with an effective biocide prior to pumping the fluid into the
well. Baker Hughes can provide a bactericide that will meet the
customer’s needs.
EC9555A
A biocide used in linear gels and fracturing fluids. EC9555A is
typically used for a quick kill of bacteria and as a preservative in
treating fluids. This product typically kills bacteria in the holding
tanks, pipes and manifolds. The recommended dosage for polymer
systems is 0.2–0.3 gal per 1,000 gal (0.2–0.3 L/cu m). The dosage
depends on the amount of bacteria present initially, time delay
before treatment, and water temperature.
Magnacide 575
A biocide used in linear gels and fracturing fluids. It is recommended
for use in controlling sulfate-reducing bacteria and general aerobic
bacteria, including microorganisms that contribute to biofilm forming
in oil field recovery. Magnacide 575 is used for a quick kill of
bacteria when loading fracturing fluid base waters onto frac boats
or into frac tanks. This product kills bacteria in the holding tanks,
pipes and manifolds. Magnacide 575 has a very good toxicity profile
and readily biodegrades. The recommended dosage for polymer
systems is 0.1–0.3 gallons per 1,000 gal (0.1–0.3 L/cu m). The
dosage depends on the amount of bacteria present initially, time
delay before treatment, and water temperature.
126
X-Cide 207
A solid biocide used to prevent the degradation of fracturing and
drilling fluids. X-Cide 207™ is a water-dispersible biocide that is
absorbed onto an inert particle for handling. It is recommended for
use in controlling sulfate-reducing bacteria, anaerobic and general
aerobic bacteria. The recommended dosage for polymer systems
is 0.3–1.0 lb per 1,000 gal (36–120 g/cu m). The dosage depends
on the amount of bacteria present initially, time delay before
treatment, and water temperature.
Foaming Agents
The use of gases such as nitrogen, carbon dioxide, and natural
gases are advantageous to the oil industry. They are used in
production to lift liquids to the surface. Gases are used to assist
in the removal of treating fluids from the well and formation to
minimize the volume of liquid that a formation is subjected to during
treatment and can be use to divert treatments to obtain complete
coverage of a zone. Foaming agents are used in gas and liquid
mixture to form a stable liquid/gas emulsion thereby making the
mixture one complete fluid.
WF-117
A amphoteric surfactant foaming agent compatible with cationic
and anionic systems. WF-117 can be used in acids and fracturing
systems. It is soluble in freshwater and seawater, and dispersible in
isopropyl alcohol.
WF-117 will foam freshwater, brine, hydrochloric acids, and water
with up to 55% isopropyl alcohol. Recommended loading ranges
from 3 gal per 1,000 gal (3 L/cu m) in freshwater to 10 gal per
1,000 gal (10 L/cu m) in Hydrochloric acid (HCl). Foam stability and
compatibility should be evaluated for each application.
Friction Reducing Agent
Friction reducers are used in stimulation fluids to reduce the surface
treating pressure. Water based polymers used in fracturing gels are
frequently used for water based systems. The acid gelling agent
AG-193 is also an excellent friction reducer for acids and brines at
lower concentration. The recommended loading for use as a friction
reducer is 0.05–0.1% by volume.
Fluid Loss Control
Systems and Materials
Fluid Loss Control Systems And Materials
In all openhole completions, it is necessary to control fluid loss to
prevent hole collapse and in the case of horizontal completions
to insure there are sufficient fluid returns to gravel pack the well.
While employing pills to control losses, it is important not to
damage screen, filter cake or formation. Common pills used and
their application is as follows:
Drill-in
fluid pill - used prior to or immediately following
well displacement.
Solids free pill - sometimes spotted in the open hole to provide
shale stability.
Healer pill - used after screen is in place but before gravel
packing. Pill will pass through 20/40 mesh and larger prepacks, all EXCLUDER™ screens, and 6.0 gauge and larger wire
wrap screen.
Screen pill - used after gravel packing to bridge on the inside of
the screen.
The materials used to formulate these pills are available from
Baker Hughes
PERFFLOW DIF
Brine based drill-in fluid (BBDIF)
PERFFLOW™ DIF™ is a formulation of bridging, viscosifying,
and filtration-control agents to be used in the preparation of a
PERFFLOW system. PERFFLOW DIF is compatible with calcium
chloride, calcium bromide, or zinc bromide brines where highdensity fluids are required. PERFFLOW DIF can also be used
to formulate low-density PERFFLOW fluids using potassium or
sodium chloride brines. PERFFLOW DIF is formulated to control
leak-off and bridge a wide range of permeabilities from a few
millidarcies to over 10 darcies. The filter cake produced by
PERFFLOW DIF is easily dispersed and removed by flowing the
well and does not rely upon breakers or dissolution.
the intent is to remove the filtercake by means of breakers or
acidization rather than by means of production. The system
is suitable for use as a drill-in fluid and is thermally stable to
250°F (121°C).
OMNIFLOW DIF
(Invert emulsion drill-in fluid system)
OMNIFLOW™ DIF is a specially formulated invert emulsion
drill-in and completion fluid using any approved external phase
oil. This system is designed to minimize drilling problems and
maximize well productivity in openhole gravel pack applications.
OMNIFLOW DIF is recommended for reservoir drill-in
applications having a higher than average potential for problems
commonly associated with water-base drilling fluids. Some of
the major problems minimized by using OMNIFLOW DIF would
be (1) wellbore instability caused by hydratable shales above or
interbedded with the reservoir sands, (2) fluid instability related
to high bottom hole temperatures or, (3) excessive torque and
drag related to high angle, extended reach drilling. OMNIFLOW
DIF is recommended for drilling horizontal wells in consolidated
or unconsolidated reservoirs, especially when the reservoir
section includes exposed shales and open-hole completion
techniques are used.
Baker Clean Gel I
Baker Clean Gel I™ (BC Gel I) is a viscous non-crosslinked
polymer system prepared using a HEC polymer that can viscosify
low and high-density brines such as potassium chloride, sodium
chloride, calcium chloride, calcium bromide and/or zinc bromide.
Baker Clean Gel I formulated with a high polymer loading can be
used as a viscous pill that can be spotted across a production
interval to control fluid loss and formation sand sloughing.
PERFFLOW 100
Brine based drill-in fluid (BBDIF)
PERFFLOW 100 is compatible with calcium chloride, potassium
chloride, sodium chloride, sodium bromide and formate salts.
PERFFLOW 100 is formulated to control leak-off and bridge a
wide range of permeability from a few millidarcies to over 10
darcies. The filter cake produced by PERFFLOW 100 is easily
dispersed and removed by flowing the well and does not rely
upon breakers or dissolution. This system is also designed to
be used in low temperature reservoirs (±100°F/[38°C]) where
127
Fluid Loss Control
Bridging Agents
Permanent Blocking Agents
Bridging agents may be used in fluid loss control systems when
the system alone is not adequate enough to control fluid loss.
Permanent blocking agents can be used to permanently shutoff
produced water, for zonal isolation or modification of injection
profiles in injector wells and the plugging of thief zones in
formations to control fluid losses.
Mini-Carb
Fine calcium carbonate with a median particle size of 6.0 microns.
It is the bridging agent used in the healer pill.
Mil-Carb
Calcium carbonate with a median particle size of 13 microns.
It is the bridging agent used in the drill-in fluid pill.
B-641Q
It is one of the bridging agents used in the screen pill.
BS-648
It is one of the bridging agents used in the screen pill.
FLC-306
A suspension of polymer and starch used to build
PERFFLOW™ DIF™ drill-in fluid. An additional amount of
FLC-306 , if needed, can be added to the system to increase
viscosity and filtration control. Can be used a solids-free pill
following displacement of PERFFLOW DIF prior to openhole
gravel packing.
™
FLC-309
A blend of polymer and starch used to build PERFFLOW DIF
drill-in fluid. An additional amount of
FLC-309™, if needed, can be added to the system to increase
viscosity and filtration control.
W-308
A suspension of polymer and starch used to build
PERFFLOW 100 drill-in fluid. An additional amount of
W-308™, if needed, can be added to the system to increase
viscosity and filtration control. Can be used a solids-free pill
following displacement of PERFFLOW 100 prior to openhole
gravel packing.
128
PoroPlug
PoroPlug™ is a patent pending fluid system designed for treating
the near wellbore area to shutoff produced water. The system
works by creating a ridged gel that fills and blocks the flow
channels eliminating the permeability. It is used for zonal
isolation or modification of injection profiles in injector wells
and the plugging of thief zones in formations. In loss circulation
applications the treatment is pumped into the thief zone or other
highly permeable formations to control fluid losses.
PoroPlug system consists of an aqueous silicate solution that
is activated when a hardener is added prior to pumping thus
forming a single staged treatment. The treatment and spacer
volume is based on pore volume calculations designed to treat
the desired depth and height of penetration. The base fluid
must be fresh water and to avoid possible incompatibles with
wellbore and formation fluids treated fresh water spacers are
placed in front and behind the PoroPlug system.
The fluid is pumped into the zone to be treated and a specified
amount of time is allowed for the fluid to form a uniform hard
gel in-situ. The gelation time, which is controlled by an internal
activator, can be adjusted from
0.5 to 12 hours to meet the needs of the well parameters.
The application temperatures are from 70°F–270°F
(21°C–132°C). The fluid has very low viscosity (1–3 cp)
and is solids free which ensures deep matrix penetration.
The system is highly biodegradable and low in toxicity.
Fluid Loss Control
Properties
Compatibilities
Temperature
PoroPlug
ranges can be 70°F–270°F (21°C–132°C)
of 1–3 cps
Specific Gravity: 1.3–1.5
Controlled gelling time
Internally activated
Solids free
Activates in the presence of divalent ions
Viscosity
is compatible with:
• Fresh water
• Clay control agents
PoroPlug is not compatible with:
• Acids, reacts with weak acidic gases like hydrogen sulfide,
sulfur dioxide, and carbon dioxide
• Salts, common mono valiant and divalent salts
(i.e., KCl, CaCl2)
Benefits
Permanent
plug
stage treatment
Predictable performance characteristics
Low viscosity provides deep penetration
Compatibility with clay control agents permitting deeper
penetration in formations containing reactive clays
Can be mixed on the fly or batch mixed
Highly biodegradable and is low in toxicity
Single
Photographs of PoroPlug™ demonstrating gel strength
Suspending 20–40 mesh US sand after 24 Hours
40 ml 6.7% FLC-1L + 1.5 ml
FLH-1L at 70° F
before gelation
40 ml 6.7% FLC-1L + 1.5 ml
FLH - 1L at 70° F after gelation,
cup inverted
40 ml 6.7% FLC - 1L + 1.5 ml FLH 1L at 70° F after gelation, cup removed
129
130
Hole/Casing Cleaning
Systems and Chemicals
Hole Cleaning Systems
Productivity is directly related to hole cleaning. The greater the
effort to clean the hole, the higher the productivity. Through
observation and feedback from clients, Baker Hughes has
developed and refined a number of hole cleaning systems and
techniques. These techniques require a variety of pills to displace
the drill-in fluid, and clean the open or cased hole. Baker Hughes
division has developed a product line to meet the needs of
the customer.
CASING WASH 100
CASING WASH™ 100 is a blend of surfactants in a mixed alcohol
system designed for the clean up of casing, drillpipe and surface
equipment before the completion operation. CASING WASH 100
removes water-base mud, sand and polymer from all surfaces
including casing, drillpipe, tanks, pumps, lines and shale shakers.
CASING WASH 100 is used as one of the mud displacement/
casing clean up pills prior to a gravel pack or frac pack operation.
Its use reduces the time needed for filtering the completion fluid
to acceptable levels. The treatment level for cleaning surface
equipment is 1 drum per 50 barrels of brine or water. For wellbore
clean up, the pill volume containing the CASING WASH 100
is generally 1% of the wellbore volume that is targeted for
cleaning. Of that volume, 5% should be CASING WASH 100.
For specific applications, technical information is available
from your Baker Hughes Completion or Drilling Fluids
technical representative.
CASING WASH 200
CASING WASH™ 200 is a blend of surfactants and alcohol
system designed for the clean up of casing, drillpipe and surface
equipment in preparation for an openhole completion.
CASING WASH 200 removes water-base mud debris containing
up to 6% by volume oil or synthetic based products. Like
CASING WASH 100, this product also removes sand and polymer
from all surfaces including casing, drillpipe, tanks, pumps,
lines and shale shakers. CASING WASH 200 is recommended
for cleaning the water-base mud and debris containing oil or
synthetic base fluid concentrations up to 6% by volume from
the casing prior to a completion operation. The treatment level
for cleaning surface equipment is 1 drum per 50 barrels of brine
or water. For wellbore clean up, the pill volume containing the
CASING WASH 200 is generally 1% of the wellbore volume that is
targeted for cleaning. Of that volume, 8% should be
CASING WASH 200. For specific applications, technical
information is available from your Baker Hughes Completion or
Drilling Fluids technical representative.
FLOW-CLEAN
FLOW-CLEAN™ is a versatile, highly effective solvent used for
the complete removal of oil base and synthetic drilling fluids,
and residue from workstring and open hole during displacement
operations. FLOW-CLEAN can be used to flush mud lines, surface
pits and equipment prior to the displacement of oil and synthetic
base drilling fluids with a completion brine. When used as an
openhole solvent to clean and scour an OMNIFLOW™ DIF™ or
invert emulsion filter cake during displacement, it effectively
removes excess oil and emulsifier so that brine placed across
the reservoir will be free of damaging emulsions. This condition
is required prior to gravel packing or frac packing. When used
in conjunction with FLOW-SURF™, FLOW-CLEAN is especially
effective in cleaning the casing prior to gravel packing or frac
packing operations. FLOW-CLEAN is used for the removal of oil
and synthetic base drilling fluids and residue from the casing and
reservoir. Generally, when scouring the open hole prior to gravel
packing, FLOW-CLEAN is added to brine in the lead displacement
pill at 5% by volume. When used to clean the casing, the solvent
is added neat. Since the displacement of and complete removal of
fluid debris is based on the pump rate, contact time and saturation
factor of FLOW-CLEAN, each displacement application is designed
on a well by well basis. Contact your Baker Hughes Completion
or Drilling Fluids technical representative for recommendations
concerning your displacement application.
131
FLOW-CLEAN R
FLOW-SURF
FLOW-CLEAN R is a maximum strength, eco-friendly wellbore
displacement additive for complete removal of oil and synthetic
base mud systems from a deepwater riser. FLOW-CLEAN R is
an innovative, environmentally friendly concentrated mixture
of solvents and surfactants for riser cleanup. FLOW-CLEAN R is
dispersible in seawater; therefore, it can be diluted with seawater
to a desired level for cleaning operations. The dilute solution can
also clean all surface tanks, lines and manifolds. When used in
conjunction with FLOW-SURF™, deepwater risers may be cleaned
and water-wetted prior to the completion operation. FLOW-CLEAN
is used for the removal of oil and synthetic base drilling fluids and
residue from the casing and reservoir. Since the displacement
of and complete removal of fluid debris from a riser is based on
the pump rate,contact time and saturation factor of
FLOW-CLEAN R, each displacement application is designed on
a well by well basis. Normally, a 2%–5% solution is required
to clean risers of any size with a brushing tool. Baker Hughes
Completion or Drilling Fluids Technical Representative will provide
specific recommendations for your displacement design.
FLOW-SURF™ is a concentrated blend of nonionic surfactants
and special alcohols designed for de-emulsifying oil or synthetic
base muds, and water wetting casing surfaces. FLOW-SURF
can penetrate an oil or synthetic base drilling fluid wall cake
and residue, thereby allowing them to be circulated out and
completely removed from the wellbore during the casing
displacement process. When used in casing displacements,
FLOW-SURF works in conjunction with FLOW-CLEAN to help clean
and scour metal surfaces contaminated with oil or synthetic base
muds, thus allowing metal surfaces to become water wet. When
used in conjunction with FLOW-CLEAN SS before cementing
operations, FLOW-SURF water wets the casing and formation
to ensure adhesion of the cement to the wellbore. FLOW-SURF
is designed to water wet casing and formation surfaces during
the displacement of oil and synthetic base muds. This product
is normally added to filtered completion brine at a level of 1%
by volume and is part of the Tail Casing Sweep. The pump rate
and desired contact time may vary the final concentration in
the brine. Baker Hughes Completion or Drilling Fluids technical
representative will provide specific recommendations for your
displacement design.
™
FLOW-CLEAN SS
FLOW-CLEAN™ SS is a versatile, highly effective solvent used for
the complete removal of oil base and synthetic drilling fluids, and
residue from the wellbore prior to water injection.
FLOW-CLEAN SS is an innovative, environmentally friendly,
concentrated downhole-cleaning agent. When used as an
openhole solvent to completely clean and scour an OMNIFLOW
DIF or invert emulsion filter cake during displacement, it
effectively removes excess oil and emulsifier so that the
reservoir can be prepared for water injection. FLOW-CLEAN SS
is especially formulated to penetrate, dissolve and remove oil
base and synthetic oil base drilling fluid wall cake, whole mud
and filtrate lost to the formation. FLOW-CLEAN SS is designed to
synergistically work together with FLOW-SURF™ PLUS.
FLOW-CLEAN SS is a fast, effective, non-toxic and non-corrosive
solvent especially designed for use in horizontal and vertical
wellbore stimulation and cleanup. Since the displacement of
and complete removal of fluid debris is based on the pump
rate, contact time and saturation factor of FLOW-CLEAN SS,
each displacement application is designed on a well by well
basis. Baker Hughes Completion or Drilling Fluids technical
representative will provide specific recommendations for your
displacement design.
132
FLOW-SURF PLUS
FLOW-SURF PLUS is very powerful water-wetting agent
composed of a blend of anionic and nonionic surfactants and an
environmentally safe solvent. FLOW-SURF PLUS can penetrate an
oil or synthetic base drilling fluid wall cake and residue, thereby
allowing them to be circulated out and completely removed
from the wellbore during the casing displacement process. The
surfactant in this product prevents the oil droplets and mud
particles from re-aggregating and reattaching themselves to
the wellbore, thus allowing the metal surfaces to become
water-wet. For stimulation applications such as water injection,
FLOW-SURF PLUS changes the interfacial tension of an oil
or synthetic base filter cake so that FLOW-CLEAN SS can
penetrate, allowing the cake and residuals to be removed via
circulation. FLOW-SURF PLUS is designed to water-wet casing
surfaces during the displacement of oil and synthetic base
muds to PERFFLOW DIF. In addition, FLOW-SURF PLUS is used
as a stimulation additive along with FLOW-CLEAN SS in waterinjection applications. This product is normally added to filtered
completion brine at a level of 1% by volume and is part of the
tail casing sweep. The pump rate and desired contact time may
vary its final concentration in the brine. Baker Hughes Completion
or Drilling Fluids technical representative will provide specific
recommendations for your displacement design.
MS-90
MS-90™ is a mutual solvent (ethylene glycol monobutyl ether).
MS-90 is completely soluble in water or clean brine and when
used for clean up, aids in the removal of oil or synthetic base
fluids from the wellbore. When used in conjunction with
FLOW-CLEAN™, MS-90 is especially effective in cleaning the
open hole after drill-in with SYN-TEQ™ or OMNIFLOW™ DIF™ in
preparation for a gravel pack completion. MS-90 is used for the
removal of excess oil and synthetic base drilling fluid (base fluid
and emulsifier) and residue from the filter cake deposited on the
reservoir face. Generally, when scouring the open hole prior to
gravel packing or frac packing, MS-90 is added to brine in the
lead displacement pill at 5% by volume. Contact your
Baker Hughes Completion or Drilling Fluids technical
representative for volume recommendations concerning your
displacement and clean-up application.
133
Pipe Pickling Systems and Chemicals
Since cleanliness is paramount, it is necessary to remove rust,
scale and pipe dope from the workstring before beginning any
operation. Pumping a solvent sweep followed by an acid sweep
usually does this. The sweep is forward circulated to within
300 –500 ft (91.4–.4 m) of the end of the string or a reversing port
and then reversed out. Volume of treatment is matched to pump
rate to give five minutes of contact time.
DOPE-FREE
DOPE-FREE™ is a highly effective pipe pickling solvent with proven
success in dissolving a wide range of pipe dopes from downhole
tubulars. DOPE-FREE may be used to completely remove oil,
grease and residue from the casing, workstring, tubulars, pits and
lines. DOPE-FREE in combination with the pipe pickling acid works
to eliminate stubborn pipe scale, rust, cement, mud contamination
and other foreign debris that can cause major wellbore damage
and even costly failures during well completion operations.
DOPE-FREE is primarily used to pickle the workstring or tubing
during the preparation for a completion operation. Each fluid
should be pumped separately to the end of the workstring at the
desired pump rate, and reversed out.
134
DOPE-FREE ZN
DOPE-FREE™ ZN is a highly effective pipe pickling solvent with
proven success in dissolving a wide range of pipe dopes from
downhole tubulars, including ZN-50. DOPE-FREE ZN may be used
to completely remove oil, grease and residue from the casing,
workstring, tubulars, pits and lines. DOPE-FREE ZN in combination
with the pipe pickling acid works to eliminate stubborn pipe
scale, rust, cement, and mud contamination that can cause
major wellbore damage and even costly failures during well
completion operations. DOPE-FREE ZN is primarily used to pickle
the workstring or tubing during the preparation for a completion
operation after the use of ZN-50 pipe dope. Each fluid should be
pumped separately to the end of the workstring at the desired
pump rate, and reversed out.
Prop FLUSH
The Prop FLUSH™ fluid system is a specialty fluid used to flush and
remove residual proppant slurry from crossover tools and the work
string to mitigate tool sticking during frac pack operations.
As the viscous slurry wets the metal surfaces of the tool and
workstring, the elasticity of the fluid will resist separation from
the surface metal when stressed. The mechanisms for this type
of adhesion are mechanical adhesion and specific adhesion. The
adhesion of proppant in a slurry that contains no polymer is due
to the electrostatic charge difference between the metal surface
and the surface of the proppant. This type of adhesive force can be
significant when using ceramic proppant.
The Prop FLUSH fluid system is composed of a proprietary micellar
fluid and a buffered solution that is added to the base brine of
the fracturing or completion fluid. The surfactant package in the
Prop FLUSH system addresses the adhesion and static charge
properties and the buffered solution reduces the viscosity of the
gelled proppant carrier fluid.
Features/Benefits
Can
be prepared with the following fluids: Fresh water, filtered
sea water, 0–24% KCl, 0–26% NaCl, CaCl2 up to 11.7 ppg,
CaBr2 up to 14.2 ppg and CaCl2/CaBr2
Can be prepared with the following fluids pending laboratory
approval: MgCl2, NH4Cl, K2CO3, KBr, NaBr, Zn
Brines, formate brines
Cost effective
Can be batch mixed with standard equipment
Easy to spot
Properties
Surfactant
package addresses adhesion and static
charge properties
A buffered solution is used to reduce the viscosity of the
carrier fluid
A spacer must be used to separate the fluid from the high pH
crosslinked frac fluid
In a typical application, Prop FLUSH fluid is spotted in the annulus Temperature range from 50°F–300°F (10°C–150°C).
and on completion of the frac pack treatment, the tool is moved to Prop FLUSH is compatible with all non-ionic surfactants and
with most Brines
the evacuate position and the Prop FLUSH fluid is pumped from the
backside through the tool and up the tubing string to flush or wash Prop FLUSH is not compatible with high ph frac fluids and any
mixing will make them less sable and must beseparated by a
the slurry from the tools and workstrings. The fluid can be used in
brine spacer
applications from 50°F–300°F (10°C–150°C).
135
136
Appendix
Wentworth’s Particle Size Classification
Grain Size
in.
Grain Size
Name
mm
in.
mm
> 10
> 256
Boulder
0.02 - 0.01
1/2 - 1/4
10 - 5
256 - 128
Large cobble
0.01 - 0.005
1/4 - 1/8
Fine sand
5 - 2.5
128 - 64
Small cobble
0.005 - 0.0025
1/8 - 1/16
Very fine sand
2.5 - 1.25
64 - 32
V. Large pebble
0.0025 - 0.0012
1/16 - 1/32
Coarse silt
Medium sand
Medium silt
1.25 - 0.64
32 - 16
Large pebble
0.0012 - 0.0006
1/32 - 1/64
0.64 - 0.32
16 - 8
Medium Pebble
0.0006 - 0.0003
1/64 - 1/128
Fine silt
0.32 - 0.16
8-4
Small pebble
0.0003 - 0.00015
1/128 - 1/256
Very fine silt
0.16 - 0.08
4-2
Granule
0.00015 - 0.000075
1/256 - 1/512
Coarse clay
0.08 - 0.04
2-1
Very coarse sand
0.000075 - 0.000038
1/512 - 1/1024
Medium clay
0.04 - 0.02
1 - 1/2
Coarse sand
0.000038 - 0.00002
1/1024 - 1/2048
Fine clay
Technical Data on Gravel Pack Sand
Permeability of Gravel
Standard Sieve Openings
Sieve Opening
U.S. Mesh Size Range
Permeability (Darcies)
6-10
2,703
in.
mm
Equivalent f
Units
2.5
0.315
8.000
-3.0
8-12
1,969
3
0.265
6.730
-2.75
10-20
652
3.5
0.223
5.660
- 2.5
12-20
518
4
0.187
4.760
-2.25
16-25
391
5
0.157
4.000
-2.0
16-30
398
6
0.132
3.360
-1.75
20-40
136
7
0.111
2.830
-1.5
30-40
138
8
0.0937
2.380
-1.25
30-50
100
10
0.0787
2.000
-1.0
40-60
61
12
0.0661
1.680
-.75
50-70
32
14
0.0555
1.410
-.5
16
0.0469
1.190
-.25
18
0.0394
1.000
0
20
0.0331
0.840
.25
25
0.0280
0.710
.50
30
0.0232
0.589
.76
35
0.0197
0.500
1
40
0.0165
0.420
1.25
45
0.0138
0.351
1.5
D50=Gravel pack sand medium grain size
50
0.0117
0.297
1.75
d50 =formation medium grain size
60
0.0098
0.250
2.0
70
0.0083
0.210
2.25
80
0.0070
0.177
2.5
d40 = 40% cumulative formation grain size
100
0.0059
0.149
2.75
d90 = 90% cumulative formation grain size
120
0.0049
0.124
3.0
140
0.0041
0.104
3.25
170
0.0035
0.088
3.5
200
0.0029
0.074
3.75
230
0.0024
0.062
4.00
270
0.0021
0.053
4.25
325
0.0017
0.044
4.5
400
0.0015
0.037
4.75
U.S. Mesh Size

Name
* Based on average porosity of 38 percent. Baker Hughes standard gravel
permeability as per Fair & Hatch procedure from Bear, J. “Dynamics of Fluids
in a Porous Media” 1988, Dover Publications Inc. NY pp 133-135
Gravel Pack Sand Sizing
Use
If
4d50 < D50 < 8d50
highly non-uniform (Cu > 5) consider using next smaller size.
Cu =d40/d90
f = log2 1/D (mm)
137
Appendix
Fracturing Sand and Ceramic Proppant
Information compiled courtesy of Borden Chemical Company
API Mesh
Proppant Tradename
Size
Particle Density
g/cm³
lbm/gal
Specific Volume
cm³/g
gal/ lbm
Bulk Density
Pipe Fill Factor
g/cm³
lbm/ft³
cm³/g
gal/lbm
ft³/lbm
Fracturing Sand
Ottawa type1
Brady type2
20/40
2.65
22.11
0.377
0.0452
1.64
102
0.610
0.0731
0.0098
16/30
2.65
22.11
0.377
0.0452
1.58
99
0.633
0.0758
0.0101
12/20
2.65
22.11
0.377
0.0452
1.53
96
0.654
0.0783
0.0105
30/50
2.65
22.11
0.377
0.0452
1.64
102
0.610
0.0731
0.0098
40/70
2.65
22.11
0.377
0.0452
1.64
102
0.610
0.0731
0.0098
20/40
2.65
22.11
0.377
0.0452
1.61
101
0.621
0.0744
0.0099
16/30
2.65
22.11
0.377
0.0452
1.62
101
0.617
0.0740
0.0099
12/20
2.65
22.11
0.377
0.0452
1.60
100
0.625
0.0749
0.0100
8/16
2.65
22.11
0.377
0.0452
1.57
98
0.637
0.0763
0.0102
Sintered Ceramic Proppant
Economy3
20/40
2.68
22.36
0.373
0.0447
1.54
96
0.649
0.0778
0.0104
30/50
2.63
21.95
0.380
0.0456
1.54
96
0.649
0.0778
0.0104
20/40
2.75
22.95
0.364
0.0436
1.63
102
0.613
0.0735
0.0098
16-18/30
2.73
22.78
0.366
0.0439
1.66
104
0.602
0.0722
0.0096
Light weight4
16/20
2.62
21.86
0.382
0.0457
1.65
103
0.606
0.0726
0.0097
12/18
2.69
22.45
0.372
0.0445
1.64
102
0.610
0.0731
0.0098
20/40
3.15
26.29
0.317
0.0380
1.86
116
0.538
0.0644
0.0086
16-18/30
3.17
26.45
0.315
0.0378
1.79
112
0.559
0.0669
0.0089
Intermediate density5
16/20
3.11
25.95
0.322
0.0385
1.81
113
0.552
0.0662
0.0089
12/18-20
3.25
27.12
0.308
0.0369
1.80
112
0.556
0.0666
0.0089
20/40
3.55
29.63
0.282
0.0338
1.98
124
0.505
0.0605
0.0081
16-18/30
3.55
29.63
0.282
0.0338
2.00
125
0.500
0.0599
0.0080
High density (bauxite)6
16/20
3.55
29.63
0.282
0.0338
2.08
130
0.481
0.0576
0.0077
12/18-20
3.55
29.63
0.282
0.0338
2.08
130
0.481
0.0576
0.0077
30/50-60
3.55
29.63
0.282
0.0338
2.08
130
0.481
0.0576
0.0077
Notes:
138
Mining Company
Quarry City
State
Geologic Name
1 Ottawa type frac sands include:
a-quartz
Badger Mining Corporation
Unimin Corporation
U.S. Silica
Taylor
Kasota
Ottawa
Wisconsin
Minnesota
Illonois
Ironton/Galesville Sandstone
Jordon Sandstone
St. Peter Sandstone
2 Brady type frac sands include:
a-quartz
Oglebay Norton Industrial Sand
Unimin Corporation
Voca & Brady
Voca
Texas
Texas
Hickory Sandstone
Hickory Sandstone
Ceramic Proppant Manufacturer
Product
Particle Density Primary g/cm3
3 Economy ceramic proppants include:
Carbo Ceramics, Inc
Norton Alcoa Proppants
Econoprop
Valuprop™
2.70
2.63
4 Light weight ceramic proppants include:
Carbo Ceramics, Inc
CarboLite®
NapLite™
2.71
2.60
5 Intermediate density ceramic proppants include:
Carbo Ceramics, Inc
CarboProp®
InterProp®
3.27
3.20
6 High Density Ceramic proppants include:
Carbo Ceramics, Inc
Sintex Minerals & Services, Inc.
CarboHSP™
Sintered Bauxite®
SinterBall
3.56
3.49
3.60
®
Appendix
Common Gravel Pack Sand Sizes and Recommended Screen Gauge
U.S. Mesh Size Range
Grain Diameter Range
Median Grain Diameter
Median Grain Diameter
in.
in.
Microns
Recommended Screen Gauge
8-12
.0937-.0661
.0799
2,029
40
10-20
.0787-.0331
.0559
1,420
20
12-20
.0661-.0331
.0496
1,260
20
16-25
.0469-.0280
.0388
986
20
16-30
.0469-.0232
.0351
892
18
20-40
.0331-.0165
.0248
630
12
30-40
.0232-.0165
.0199
505
12
30-50
.0232-.0117
.0175
445
8
40-60
.0165-.0098
.0132
335
6
50-70
.0117-.0083
.0100
254
6
Slurry Calculations
Clean Fluid Volume Required
Vf =
Where:
Sand Feed Rate
Gw
Wg
Qg =
Vf = clean fluid volume required (gal)
Gw = weight of gravel required (lb)
Wg = gravel mix ratio (ppg)
Slurry Volume
Where:
Wg =
Vs = slurry volume (bbl)
Vf = clean fluid volume (bbl)
Dsv = specific volume of gravel (gal/lb)
Slurry Density
Where:
Qg
42Qs-DsvQg
Qs = slurry rate (bbl/min)
Qg = sand rate (lb/min)
Settling Factor
Ds =
Where:
Qs = slurry rate (bbl/min)
Qg = sand rate (lb/min)
Gravel Mix Ratio
Vs = Vf (1+DsvWg)
Where:
(
42Qs
1 +D
sv)
Wg
Db+Wg
1+DsvWg
SF =
Ds = slurry density (ppg)
Db = base fluid density (ppg)
Where:
Wg(Dbv)
x100
1+Dsv(Wg)
SF = settling factor (%)
Dbv = bulk volume (gal/lb) = 1/bulk density
Dsv = specific volume of gravel (gal/lb) = 1/particle density
Specific Volume of Common Gravels and Proppants
Specific Volume (Dsv)
(gal/lb)
Natural Sand
0.0452
Econoprop®
0.0444
CarboLite®
0.0443
CarboProp®
0.0367
Bauxite
0.0336
139
Appendix
Sand Feed Rate
(lb/min) (Assuming Ottawa Sand) 1.0 –10.0
140
Sand Mix
Ratio
(ppga)
1.0
1.5
2.0
2.5
3.0
3.5
4.0
4.5
Slurry Rate (bpm)
0.25
10
16
21
26
31
36
42
47
52
57
62
67
73
78
83
88
0.50
21
31
41
51
62
72
82
92
103
113
123
133
144
154
164
175
0.75
30
46
61
76
91
107
122
137
152
168
183
198
213
228
244
259
1.00
40
60
80
100
121
141
161
181
201
221
241
261
281
301
321
1.25
50
75
99
124
149
174
199
224
248
273
298
323
348
373
1.50
59
88
118
147
177
206
236
265
295
324
354
383
413
442
1.75
68
102
136
170
204
238
272
306
340
374
408
442
476
2.00
77
115
154
192
231
269
308
346
385
423
462
500
2.25
86
129
171
214
257
300
343
386
429
471
514
2.50
94
141
189
236
283
330
377
424
471
518
566
2.75
103
154
205
257
308
359
411
462
513
564
3.00
111
166
222
277
333
388
443
499
554
3.25
119
178
238
297
357
416
476
535
3.50
127
190
254
317
380
444
507
570
3.75
135
202
269
336
404
471
538
4.00
142
213
284
355
426
497
4.25
150
224
299
374
449
4.50
157
235
314
392
470
4.75
164
246
328
410
5.00
171
257
342
5.25
178
267
5.5
185
277
5.75
191
6.00
5.0
5.5
6.0
6.5
7.0
7.5
8.0
8.5
9.0
9.5
10.0
93
99
104
185
195
205
274
289
305
341
362
382
402
397
422
447
472
497
472
501
531
560
590
511
545
579
613
647
681
539
577
616
654
693
731
770
557
600
643
686
729
771
814
857
613
660
707
754
801
848
895
943
616
667
718
770
821
872
924
975
1026
610
665
720
776
831
887
942
998
1053
1108
594
654
713
773
832
892
951
1010
1070
1129
1189
634
697
761
824
887
951
1014
1078
1141
1204
1268
605
673
740
807
874
942
1009
1076
1143
1211
1278
1345
568
639
710
781
853
924
995
1066
1137
1208
1279
1350
1421
523
598
673
748
822
897
972
1047
1121
1196
1271
1346
1420
1495
549
627
706
784
863
941
1019
1098
1176
1255
1333
1411
1490
1568
492
574
656
738
820
902
984
1066
1148
1230
1312
1394
1476
1558
1640
428
513
599
684
770
855
941
1026
1112
1197
1283
1368
1454
1539
1625
1710
356
445
534
623
712
801
890
978
1067
1156
1245
1334
1423
1512
1601
1690
1779
369
462
554
646
739
831
923
1016
1108
1200
1293
1385
1477
1570
1662
1754
1847
287
383
478
574
670
765
861
957
1052
1148
1244
1339
1435
1531
1626
1722
1818
1913
198
297
396
495
594
693
791
890
989
1088
1187
1286
1385
1484
1583
1682
1781
1880
1979
6.25
204
306
409
511
613
715
817
919
1021
1124
1226
1328
1430
1532
1634
1736
1839
1941
2043
6.50
211
316
421
526
632
737
842
948
1053
1158
1263
1369
1474
1579
1685
1790
1895
2001
2106
6.75
217
325
434
542
650
759
867
975
1084
1192
1301
1409
1517
1626
1734
1843
1951
2059
2168
7.00
223
334
446
557
669
780
891
1003
1114
1226
1337
1449
1560
1671
1783
1894
2006
2117
2229
7.25
229
343
458
572
687
801
915
1030
1144
1259
1373
1487
1602
1716
1831
1945
2060
2174
2288
7.50
235
352
469
587
704
822
939
1056
1174
1291
1408
1526
1643
1760
1878
1995
2113
2230
2347
7.75
241
361
481
601
722
842
962
1082
1203
1323
1443
1563
1684
1804
1924
2044
2165
2285
2405
8.00
246
369
492
615
739
862
985
1108
1231
1354
1477
1600
1723
1846
1970
2093
2216
2339
2462
8.25
252
378
504
629
755
881
1007
1133
1259
1385
1511
1637
1762
1888
2014
2140
2266
2392
2518
8.50
257
386
515
643
772
900
1029
1158
1286
1415
1544
1672
1801
1930
2058
2187
2316
2444
2573
8.75
263
394
525
657
788
919
1051
1182
1313
1445
1576
1707
1839
1970
2102
2233
2364
2496
2627
9.00
268
402
536
670
804
938
1072
1206
1340
1474
1608
1742
1876
2010
2144
2278
2412
2546
2680
9.25
273
410
546
683
820
956
1093
1230
1366
1503
1639
1776
1913
2049
2186
2323
2459
2596
2732
9.50
278
418
557
696
835
974
1114
1253
1392
1531
1670
1810
1949
2088
2227
2366
2506
2645
2784
9.75
283
425
567
709
850
992
1134
1276
1417
1559
1701
1843
1984
2126
2268
2409
2551
2693
2835
10.00
288
433
577
721
865
1010
1154
1298
1442
1587
1731
1875
2019
2163
2308
2452
2595
2740
2885
Appendix
Sand Feed Rate
(lb/min) (Assuming Ottawa Sand) 11.0–40.0
Sand
Mix
Ratio
(ppga)
11.0
12.0
13.0
14.0
15.0
16.0
17.0
18.0
Slurry Rate (bpm)
19.0
20.0
22.0
23.0
24.0
25.0
27.5
30.0
35.0
40.0
0.25
114
125
135
145
156
166
176
187
197
208
228
239
249
260
285
311
363
415
0.50
226
246
267
287
308
329
349
370
390
411
452
472
493
513
565
616
719
821
0.75
335
365
396
426
457
487
518
548
579
609
670
701
731
761
838
914
1066
1218
1.00
442
482
522
562
603
643
683
723
763
803
884
924
964
1004
1105
1205
1406
1607
1.25
546
596
646
695
745
795
844
894
944
993
1093
1142
1192
1242
1366
1490
1738
1987
1.50
649
708
767
826
885
943
1002
1061
1120
1179
1297
1356
1415
1474
1622
1769
2064
2359
1.75
749
817
885
953
1021
1089
1157
1225
1293
1361
1497
1566
1634
1702
1872
2042
2382
2723
2.00
847
924
1001
1078
1155
1232
1309
1386
1463
1540
1694
1771
1848
1924
2117
2309
2694
3079
2.25
943
1028
1114
1200
1286
1371
1457
1543
1628
1714
1886
1971
2057
2143
2357
2571
3000
3428
2.50
1037
1131
1225
1320
1414
1508
1602
1697
1791
1885
2074
2168
2262
2356
2592
2828
3299
3770
2.75
1129
1232
1334
1437
1539
1642
1745
1847
1950
2053
2258
2360
2463
2566
2822
3079
3592
4105
3.00
1219
1330
1441
1552
1663
1773
1884
1995
2106
2217
2438
2549
2660
2771
3048
3325
3879
4433
3.25
1308
1427
1545
1664
1783
1902
2021
2140
2259
2378
2615
2734
2853
2972
3269
3566
4161
4755
3.50
1394
1521
1648
1775
1902
2028
2155
2282
2409
2535
2789
2916
3042
3169
3486
3803
4437
5071
3.75
1480
1614
1749
1883
2018
2152
2287
2421
2556
2690
2959
3094
3228
3363
3699
4035
4708
5380
4.00
1563
1705
1847
1989
2131
2273
2415
2558
2700
2842
3126
3268
3410
3552
3907
4263
4973
5683
4.25
1645
1794
1944
2093
2243
2392
2542
2691
2841
2990
3289
3439
3589
3738
4112
4486
5233
5981
4.50
1725
1882
2039
2195
2352
2509
2666
2823
2980
3136
3450
3607
3764
3921
4313
4705
5489
6273
4.75
1804
1968
2132
2296
2460
2624
2788
2952
3116
3280
3608
3772
3936
4100
4509
4919
5739
6559
5.00
1881
2052
2223
2394
2565
2736
2907
3078
3249
3420
3762
3933
4104
4275
4703
5130
5985
6840
5.25
1957
2135
2313
2491
2669
2847
3024
3202
3380
3558
3914
4092
4270
4448
4892
5337
6227
7116
5.50
2031
2216
2401
2586
2770
2955
3140
3324
3509
3694
4063
4248
4432
4617
5079
5540
6464
7387
5.75
2105
2296
2487
2679
2870
3061
3253
3444
3635
3827
4209
4401
4592
4783
5262
5740
6697
7653
6.00
2177
2374
2572
2770
2968
3166
3364
3562
3759
3957
4353
4551
4749
4947
5441
5936
6925
7915
6.25
2247
2451
2656
2860
3064
3268
3473
3677
3881
4086
4494
4698
4903
5107
5618
6128
7150
8171
6.50
2316
2527
2738
2948
3159
3369
3580
3790
4001
4212
4633
4843
5054
5265
5791
6317
7370
8423
6.75
2385
2601
2818
3035
3252
3468
3685
3902
4119
4336
4769
4986
5203
5419
5961
6503
7587
8671
7.00
2451
2674
2897
3120
3343
3566
3789
4012
4234
4457
4903
5126
5349
5572
6129
6686
7800
8914
7.25
2517
2746
2975
3204
3433
3662
3890
4119
4348
4577
5035
5263
5492
5721
6293
6865
8010
9154
7.50
2582
2817
3051
3286
3521
3756
3990
4225
4460
4694
5164
5399
5633
5868
6455
7042
8215
9389
7.75
2646
2886
3127
3367
3608
3848
4089
4329
4570
4810
5291
5532
5772
6013
6614
7215
8418
9620
8.00
2708
2954
3200
3447
3693
3939
4185
4431
4678
4924
5416
5662
5909
6155
6770
7386
8617
9848
8.25
2770
3021
3273
3525
3777
4028
4280
4532
4784
5036
5539
5791
6043
6295
6924
7553
8812
10071
8.50
2830
3087
3345
3602
3859
4116
4374
4631
4888
5146
5660
5917
6175
6432
7075
7718
9005
10291
8.75
2890
3152
3415
3678
3940
4203
4466
4728
4991
5254
5779
6042
6305
6567
7224
7881
9194
10508
9.00
2948
3216
3484
3752
4020
4288
4556
4824
5092
5360
5896
6164
6432
6700
7370
8040
9380
10720
9.25
3006
3279
3552
3825
4099
4372
4645
4918
5192
5465
6011
6285
6558
6831
7514
8197
9564
10930
9.50
3062
3341
3619
3898
4176
4454
4733
5011
5290
5568
6125
6403
6682
6960
7656
8352
9744
11136
9.75
3118
3402
3685
3969
4252
4536
4819
5102
5386
5669
6236
6520
6803
7087
7795
8504
9921
11339
10.00
3173
3462
3750
4038
4327
4615
4904
5192
5481
5769
6346
6635
6923
7212
7933
8654
10096
11538
141
Appendix
Pump Output Tables
Single Acting Triplex Pump
Stroke
in.
4
6
8
Bore
in.
cu ft
bbl
Double Acting Triplex Pump
90% Efficiency
cu ft
bbl
Stroke
Bore
Rod D
in.
in.
in.
cu ft
100% Efficiency
bbl
cu ft
90% Efficiency
bbl
6
4.00
1.5
0.1623
0.0289
0.1460
0.0260
0.2163
0.0385
0.1947
0.0347
0.2782
0.0495
0.2503
0.0446
3.00
.0491
.0087
.0442
.0078
3.25
.0576
.0103
.0518
.0093
3.50
.0668
.0119
.0601
.0107
5.00
0.3472
0.0618
0.3125
0.0557
3.75
.0767
.0137
.0690
.0123
4.00
0.2704
0.0482
0.2434
0.0433
4.00
.0873
.0155
.0786
.0140
0.3477
0.0619
0.3129
0.0557
0.4182
0.0745
0.3763
0.0670
0.3245
0.0578
0.2921
0.0520
0.4172
0.0743
0.3755
0.0669
0.5018
0.0894
0.4516
0.0804
0.6163
0.1098
0.5547
0.0988
0.4868
0.0867
0.4381
0.0780
5.00
0.5854
0.1043
0.5269
0.0938
5.50
0.7190
0.1281
0.6471
0.1153
6.00
0.8654
0.1541
0.7789
0.1387
0.9433
0.1680
0.8490
0.1512
6.50
1.0245
0.1825
0.9220
0.1642
6.75
1.1088
0.1975
0.9979
0.1777
7.00
1.1963
0.2131
1.0766
0.1918
7.25
1.2583
0.2241
1.1325
0.2017
1.3522
0.2408
1.2170
0.2167
4.50
.1104
.0197
.0994
.0177
5.00
.1364
.0243
.1228
.0219
4.00
8
10
4.50
4.50
5.00
4.00
12
4.50
6.00
.1963
.0350
.1767
.0315
8.00
.3491
.0622
.3142
.0560
5.50
3.00
.0737
.0131
.0663
.0117
4.50
3.25
.0864
.0155
.0777
.0140
3.50
.1002
.0179
.0902
.0161
3.75
.1151
.0206
.1035
.0185
4.00
.1310
.0233
.1179
.0210
4.50
.1656
.0296
.1491
.0266
5.00
6.25
14
1.5
1.5
2.0
1.5
2.0
1.5
2.0
5.00
.2046
.0365
.1842
.0329
6.00
.2945
.0525
.2651
.0473
8.00
.5237
.0933
.4713
.0840
7.75
1.4492
0.2581
1.3043
0.2323
3.00
.0982
.0174
.0884
.0156
5.00
0.6363
0.1133
0.5727
0.1020
3.25
.1152
.0206
.1036
.0186
5.50
0.7890
0.1405
0.7101
0.1265
6.00
0.9563
0.1703
0.8607
0.1533
6.25
1.0454
0.1862
0.9408
0.1676
6.50
1.1381
0.2027
1.0245
0.1824
1.2345
0.2199
1.1110
0.1979
7.50
2.5
3.50
.1336
.0238
.1202
.0214
3.75
.1534
.0274
.1380
.0246
4.00
.1746
.0310
.1572
.0280
4.50
.2208
.0394
.1988
.0354
7.00
1.3344
0.2377
1.2010
0.2139
.0438
7.25
1.4381
0.2561
1.2943
0.2305
7.50
1.5453
0.2752
1.3908
0.2477
7.75
1.6562
0.2950
1.4906
0.2655
5.00
0.7159
0.1275
0.6443
0.1147
5.00
10
100% Efficiency
.2728
.0486
.2456
6.00
.3926
.0700
.3534
.0630
8.00
.6982
.1244
.6284
.1120
16
6.75
2.5
3.00
.1228
.0218
.1105
.0195
5.50
0.8877
0.1581
0.7989
0.1423
3.25
.1440
.0256
.1295
.0233
6.00
1.0758
0.1916
0.9682
0.1725
3.50
.1670
.0298
.1503
.0268
6.25
1.1761
0.2095
1.0584
0.1885
3.75
.1918
.0343
.1725
.0308
6.50
1.2804
0.2280
1.1523
0.2052
4.00
.2183
.0388
.1965
.0350
1.3888
0.2473
1.2499
0.2226
7.00
1.5013
0.2674
1.3511
0.2406
4.50
.2760
.0493
.2486
.0443
7.25
1.6178
0.2881
1.4561
0.2593
5.00
.3410
.0608
.3070
.0548
7.50
1.7385
0.3096
1.5647
0.2787
6.00
.4908
.0875
.4418
.0788
7.75
1.8633
0.3319
1.6769
0.2987
8.00
.8728
.1555
.7855
.1400
6.50
1.4226
0.2534
1.2804
0.2280
6.75
1.5431
0.2748
1.3888
0.2473
7.00
1.6681
0.2971
1.5013
0.2674
1.7976
0.3202
1.6178
0.2881
7.50
1.9317
0.3440
1.7385
0.3096
7.75
2.0703
0.3687
1.8633
0.3319
8.00
2.2135
0.3942
1.9921
0.3548
18
20
6.75
7.25
2.5
2.5
Notes:
1. Volumes shown are for one complete cycle or revolution.
2. To get output in volume/minute, multiply output/cycle by pump RPM.
3. For triplex double acting pump, multiply output by 1.5.
142
Appendix
Calculations for Bottom Hole Fracturing Pressure (BHFP)
(1) Fracture Gradient (Gf) x True Vertical Depth (TVD) = BHFP
(2) Fracturing Gradient (Gf) from Instantaneous Shut-in Pressure (ISIP)
Gf =
ISIP + Hydrostatic Head Pressure
TVD
(3) Eaton’s Equation
Pc =
Pr Pc n
s
=
=
=
=
ν
1-ν
(σob-Pr )+Pr
Reservoir Pore Pressure
Closure Pressure (Minimum horizontal stress in the formation)
Poisson’s Ratio for the rock
Assume n = 0.25 - 0.31 for sandstone
n = 0.30 - 0.33 for shale
Vertical stress in formation
Assume:
sob = (1 psi/ft) (TVD) - (0.558 psi/ft) (water depth)
sob = (22.6 kPa/m) (TVD) (m) - (12.62 kPa/m) (water depth) (m)
BHFP = Pc+Pnet
Pnet = Estimated Net Fracturing Pressure
= pressure in fracture - closure pressure
Typically Pnet = 100 to 500 psi (normally used 300 psi)
= (689.5 to 3,447 kPa) (normally used 2,068 kPa)
Calculations for Maximum Bottom Hole Injection Rate Below Fracturing Pressure
lmax (bbl/min) =
4.917 x 10-6 kh(Gf x TVD)-Pr
µln(re/rw)
m = Viscosity of fluid injected at reservoir temperature
k = Formation permeability
h = Vertical thickness of reservoir (ft)
re = drainage radius (ft)
rw = wellbore radius (ft)
NOTE: If drainage radius is unknown, assume: Ln (re/rw) = 8
Formulas for Hydrostatic Pressure
Ps
Where: Ps
= 0.052 x (TVD) x Mw
= Hydrostatic pressure (psi)
Ps
Where: Ps
= 0.0098 x (TVD) x Mw
= Hydrostatic pressure (kPa)
TVD
= True Vertical Depth (ft)
TVD
= True Vertical Depth (m)
Mw
= Fluid weight (lb/gal)
Mw
= Fluid weight (kg/m3)
143
Appendix
Fluid Density and Pressure (at 60°)
Density
Fluid Head
Degrees
API
Specific
Gravity
lb/gal
lb/cu ft
g/cc
psi/ft
kPa/m
Buoyancy
Factorn
Degrees
API
Density
Specific
Gravity
lb/gal
lb/cu ft
Fluid Head
g/cc
kPa/m
Buoyancy
Factorn
60
0.738
6.160
46.080
0.738
0.320
7.239
0.905
-
1.655
13.800
103.230
1.655
0.716
16.198
0.788
55
0.758
6.325
47.310
0.758
0.328
7.420
0.903
-
1.679
14.000
104.720
1.679
0.727
16.447
0.785
50
0.779
6.499
48.620
0.779
0.336
7.601
0.900
-
1.703
14.200
106.220
1.703
0.737
16.673
0.782
45
0.801
6.683
49.990
0.801
0.347
7.850
0.897
-
1.727
14.399
107.710
1.727
0.748
16.922
0.779
40
0.825
6.878
51.450
0.825
0.357
8.076
0.894
-
1.751
14.600
109.210
1.751
0.758
17.148
0.776
35
0.849
7.085
53.000
0.849
0.368
8.325
0.891
-
1.775
14.800
110.710
1.775
0.768
17.374
0.773
30
0.876
7.304
54.640
0.876
0.379
8.574
0.888
-
1.799
15.000
112.200
1.799
0.779
17.623
0.770
25
0.904
7.537
56.380
0.904
0.391
8.846
0.884
-
1.823
15.200
113.700
1.823
0.789
17.850
0.767
20
0.933
7.786
58.240
0.933
0.404
9.140
0.880
-
1.847
15.400
115.200
1.847
0.799
18.076
0.764
15
0.965
8.052
60.230
0.965
0.418
9.456
0.876
-
1.871
15.600
116.690
1.871
0.810
18.325
0.761
10
1.000
8.337
62.360
1.000
0.433
9.796
0.872
-
1.895
15.800
118.190
1.895
0.820
18.551
0.757
-
1.007
8.400
62.830
1.007
0.436
9.864
0.871
-
1.919
16.000
119.680
1.919
0.831
18.800
0.754
-
1.031
8.600
64.330
1.031
0.446
10.090
0.868
-
1.943
16.200
121.180
1.943
0.841
19.026
0.751
-
1.055
8.800
65.820
1.055
0.457
10.339
0.865
-
1.967
16.400
122.680
1.967
0.851
19.252
0.748
-
1.079
9.000
67.320
1.079
0.467
10.565
0.862
-
1.991
16.600
124.170
1.991
0.862
19.501
0.745
-
1.103
9.200
68.820
1.103
0.477
10.791
0.859
-
2.015
16.800
125.670
2.015
0.872
19.727
0.742
-
1.127
9.400
70.310
1.127
0.488
11.040
0.856
-
2.039
17.000
127.160
2.039
0.883
19.976
0.739
-
1.151
9.600
71.810
1.151
0.498
11.266
0.852
-
2.063
17.200
128.660
2.063
0.893
20.202
0.736
-
1.175
9.800
73.300
1.175
0.509
11.515
0.849
-
2.087
17.400
130.160
2.087
0.903
20.429
0.733
-
1.199
10.000
74.800
1.199
0.519
11.741
0.846
-
2.111
17.600
131.650
2.111
0.914
20.677
0.730
-
1.223
10.200
76.300
1.223
0.529
11.968
0.843
-
2.135
17.800
133.150
2.135
0.924
20.904
0.727
-
1.247
10.400
77.790
1.247
0.540
12.216
0.840
-
2.159
18.000
134.640
2.159
0.935
21.153
0.724
-
1.271
10.600
79.290
1.271
0.550
12.443
0.837
-
2.183
18.200
136.140
2.183
0.945
21.379
0.721
-
1.295
10.800
80.780
1.295
0.561
12.692
0.834
-
2.207
18.400
137.640
2.207
0.955
21.605
0.718
-
1.319
11.000
82.280
1.319
0.571
12.918
0.831
-
2.231
18.600
139.130
2.231
0.966
21.854
0.715
-
1.343
11.200
83.780
1.343
0.581
13.144
0.828
-
2.255
18.800
140.630
2.255
0.976
22.080
0.712
-
1.367
11.400
85.270
1.367
0.592
13.393
0.825
-
2.278
19.000
142.120
2.278
0.987
22.329
0.708
-
1.391
11.600
86.770
1.391
0.602
13.619
0.822
-
2.302
19.200
143.620
2.302
0.997
22.555
0.705
-
1.415
11.800
88.270
1.415
0.612
13.845
0.819
-
2.326
19.400
145.120
2.326
1.007
22.781
0.702
-
1.439
12.000
89.760
1.439
0.623
14.094
0.816
-
2.350
19.600
146.610
2.350
1.018
23.030
0.699
-
1.463
12.200
91.260
1.463
0.633
14.320
0.813
-
2.374
19.800
148.110
2.374
1.028
23.256
0.696
-
1.487
12.400
92.750
1.487
0.644
14.569
0.810
-
2.398
20.000
149.610
2.398
1.038
23.483
0.693
-
1.511
12.600
94.250
1.511
0.654
14.795
0.806
-
1.535
12.800
95.750
1.535
0.664
15.022
0.803
-
1.569
13.000
97.240
1.559
0.675
15.271
0.800
-
1.583
13.200
98.740
1.583
0.685
15.497
0.797
-
1.607
13.400
100.230
1.607
0.696
15.746
0.794
-
1.631
13.600
101.730
1.631
0.706
15.972
0.791
nBuoyancy factor is used to compensate for loss of weight when steel tubulars are
immersed in fluid.
Applicable only when tubing or casing is completely filled with fluid.
Actual hook load = length of string (ft) x weight of string (lb/ft) x Buoyancy Factor.
Formulas for Horsepower
Hydraulic Horsepower = BPM x Pressure (PSI) x .0245 =
BPM x Pressure
Hydraulic Horsepower = GPM x Pressure (PSI) x .000584
Hydraulic Horsepower = Rate (m3/min) x Pressure (MPa) x 22.4
KWatt = Rate (m3/min) x Pressure (MPa) x 16.7
Brake Horsepower =
BPM x Pressure (PSI) x .0245
Efficiency
Brake Horsepower =
GPM x Pressure (PSI) x .000584
Efficiency
Note: BPM = barrels per minute PSI = pounds per square inch
144
psi/ft
40.8
Appendix
Gradients and Densities
Fluid
lb/gal
psi/ft
Sp. Gravity
kPa/m
50° API Condensate
6.5
0.337
0.778
7.624
lsopropyl Alcohol (IPA)
6.55
0.341
0.788
7.714
Methanol
6.6
0.343
0.792
7.760
MS 100
7.34
0.382
0.882
8.642
Kerosene or Diesel
6.8
0.353
0.815
7.986
Xylene
7.23
0.376
0.868
8.506
30° API Crude
7.31
0.379
0.875
8.574
EGMBE MS 90
7.53
0.392
0.905
8.868
Fresh Water
8.33
0.433
1.000
9.796
Seawater
8.5
0.442
1.021
9.999
2% KCl
8.44
0.438
1.012
9.909
3% NH4Cl
8.44
0.438
1.012
9.909
10
0.519
1.199
11.741
10% Acetic
8.45
0.439
1.014
9.931
9% Formic
8.53
0.444
1.025
10.045
5% HCl
8.5
0.442
1.021
9.999
10% HCl
8.75
0.445
1.028
10.067
15% HCl
8.96
0.465
1.074
10.520
15% HCl with 10% MS 90
8.82
0.458
1.058
10.361
15% HCl with 5% MS 100
8.88
0.462
1.067
10.452
15% HCl - spent
9.79
0.509
1.176
11.515
28% HCl
9.5
0.493
1.139
11.153
28% HCl - spent
11.2
0.58
1.339
13.121
35% HCl
9.83
0.511
1.180
11.560
6:1.5% HCl/HF
8.65
0.45
1.039
10.180
12:3% HCl/HF
9.01
0.469
1.083
10.610
12:3% HCl/HF with 10% MS 90
8.87
0.461
1.065
10.429
12:3% HCl/HF with 5% MS 100
8.93
0.464
1.072
10.497
3% NH4Cl with 10% MS 90
8.34
0.434
1.002
9.818
Solvents
Brines
10 ppg NaCl
Acids and Overflushes
145
Appendix
Formulas for Annular Velocity
Va
Where: Va
Flow rate to obtain
desired velocity
=
1029.4 Q
Va
Dh2 - Dp2
= Annular velocity (ft/min)
Where: Va
=
1.2732 x 106 Q
(D2 - d2)
=
Annular velocity (m/min)
Flow rate (m3/min)
Q
= Flow rate (bpm)
Q
=
Dh
= Hole diameter (in.)
D
=
Hole diameter (mm)
Drillstring OD (mm)
7.854 x 10 -7 (D2-d2) x Va
Dp
= Drillstring OD (in.)
d
=
Q
= 0.0009714 (Dh2 - Dp2) x Va
Q
=
Formulas for Volume and Height Between Multiple
Tubing Strings and Hole (or Casing)
Cu ft/lin ft = (D2 - d2) 0.005454
183.35
Lin ft/cu ft = 2 2
D -d
Gal/lin ft = (D2 - d2) 0.0408
Lin ft/gal =
24.51
D2 - d2
Barrels/lin ft = (D2 - d2) 0.0009714
Lin ft/barrel =
1029.4
D2 - d2
Cu m/lin m = (D2 - d2) 7.854 x 10-7
Lin m/cu m =
1273236
D2 - d2
Where: For Volume and Height between Tubing and Hole
D = Diameter of hole, inches (mm).
d = Outside diameter of tubing, inches (mm)..
For Volume and Height between Casing and Hole
D = Diameter of hole, inches (mm).
d = Outside diameter of casing, inches(mm).
For Volume and Height between Tubing and Casing
D = Inside diameter of casing, inches (mm).
d = Outside diameter of tubing, inches (mm).
For Volume and Height between Casings
D = Inside diameter of outer casing, inches (mm)..
d = Outside diameter of inner casing, inches (mm).
146
Appendix
Capacities of Various Diameter Holes
OD
in.
mm
cu ft/ft n
m3/m l
bbl/ft 
L/m
gal/ft u
6-3/8
162
0.2217
0.020593
0.0395
20.593
1.6581
6-1/2
165
0.2304
0.021408
0.0410
21.408
1.7238
6-5/8
168
0.2394
0.022240
0.0426
22.240
1.7907
6-3/4
172
0.2485
0.023087
0.0443
23.087
1.8589
6-7/8
175
0.2578
0.023950
0.0459
23.950
1.9284
7
179
0.2673
0.024829
0.0476
24.829
1.9992
7-1/8
181
0.2769
0.025723
0.0493
25.723
2.0712
7-1/4
184
0.2867
0.026634
0.0511
26.634
2.1445
7-3/8
187
0.2967
0.027560
0.0528
27.560
2.2191
7-1/2
191
0.3068
0.028502
0.0546
28.502
2.2950
7-5/8
194
0.3171
0.029460
0.0565
29.460
2.3721
7-3/4
197
0.3276
0.030434
0.0583
30.434
2.4505
7-7/8
200
0.3382
0.031424
0.0602
31.424
2.5302
8
203
0.3491
0.032429
0.0622
32.429
2.6112
8-1/8
206
0.3601
0.033451
0.0641
33.451
2.6934
8-1/4
210
0.3712
0.034488
0.0661
34.488
2.7769
8-3/8
213
0.3826
0.035541
0.0681
35.541
2.8617
8-1/2
216
0.3941
0.036610
0.0702
36.610
2.9478
8-5/8
219
0.4057
0.037694
0.0723
37.694
3.0351
8-3/4
222
0.4176
0.038795
0.0744
38.795
3.1237
8-7/8
225
0.4296
0.039911
0.0765
39.911
3.2136
9
229
0.4418
0.041043
0.0787
41.043
3.3048
9-1/8
232
0.4541
0.042191
0.0809
42.191
3.3972
9-1/4
235
0.4667
0.043355
0.0831
43.355
3.4909
9-3/8
238
0.4794
0.044535
0.0854
44.535
3.5859
9-1/2
241
0.4922
0.045730
0.0877
45.730
3.6822
9-5/8
245
0.5053
0.046942
0.0900
46.942
3.7797
9-3/4
248
0.5185
0.048169
0.0923
48.169
3.8785
9-7/8
251
0.5319
0.049412
0.0947
49.412
3.9786
10
254
0.5454
0.050671
0.0971
50.671
4.0800
10-1/8
257
0.5591
0.051945
0.0996
51.945
4.1826
10-1/4
260
0.5730
0.053236
0.1021
53.236
4.2865
10-3/8
264
0.5871
0.054542
0.1046
54.542
4.3917
10-1/2
267
0.6013
0.055864
0.1071
55.865
4.4982
10-5/8
270
0.6157
0.057203
0.1097
57.203
4.6059
10-3/4
273
0.6303
0.058556
0.1123
58.556
4.7149
10-7/8
276
0.6450
0.059926
0.1149
59.926
4.8252
11
279
0.6600
0.061312
0.1175
61.312
4.9368
11-1/8
283
0.6750
0.062713
0.1202
62.713
5.0496
11-1/4
286
0.6903
0.064130
0.1229
64.130
5.1637
11-3/8
290
0.7057
0.065563
0.1257
65.563
5.2791
11-1/2
292
0.7213
0.067012
0.1285
67.012
5.3958
11-5/8
295
0.7371
0.068477
0.1313
68.477
5.5137
11-3/4
299
0.7530
0.069957
0.1341
69.957
5.6329
11-7/8
302
0.7691
0.071454
0.1370
71.454
5.7534
12
305
0.7854
0.072966
0.1399
72.966
5.8752
12-1/8
308
0.8018
0.074494
0.1428
74.494
5.9982
12-1/4
311
0.8185
0.076038
0.1458
76.038
6.1225
 Ft/Cu Ft =
 Ft/Bbl =
1
Cu Ft/Ft
1
Bbl/Ft
m/m3=
 Ft/Gal =
1
m3/m
1
Gal/Ft
147
Appendix
Dimensions and Capacities of Casing
OD
in.
mm
4
102
114
4-1/2
121
4-3/4
127
5
133
5-1/4
140
5-1/2
146
5-3/4
 Ft/Cu Ft =
 Ft/Bbl =
148
lb/ft
1
Cu Ft/Ft
1
Bbl/Ft
m/m3=
 Ft/Gal =
kg/m
ID
in.
mm
cu ft/ft n
m3/m l
bbl/ft 
gal/ft u
5.65
8.41
3.607
94.79
0.0759
0.0071
0.0135
0.5683
9.50
14.41
3.500
88.90
0.0668
0.0062
0.0119
0.4998
11.60
17.26
3.428
87.07
0.0641
0.0060
0.0114
0.4794
6.75
10.04
4.216
107.09
0.0969
0.0090
0.0173
0.7252
9.50
14.14
4.090
103.89
0.0912
0.0085
0.0162
0.6825
10.50
15.62
4.052
102.92
0.0895
0.0083
0.0159
0.6699
11.00
16.37
4.026
102.26
0.0884
0.0082
0.0157
0.6613
11.60
17.26
4.000
101.60
0.0873
0.0081
0.0155
0.6528
12.60
18.75
3.958
100.53
0.0854
0.0079
0.0152
0.6392
13.50
29.09
3.920
99.57
0.0838
0.0078
0.0149
0.6269
15.10
22.47
3.826
97.18
0.0798
0.0074
0.0142
0.5972
16.60
24.70
3.754
95.36
0.0769
0.0071
0.0137
0.5750
18.80
27.97
3.640
92.46
0.0723
0.0067
0.0129
0.5406
9.50
14.14
4.364
110.85
0.1039
0.0097
0.0185
0.7770
16.00
23.81
4.082
103.68
0.0909
0.0084
0.0162
0.6798
18.00
26.78
4.000
101.60
0.0873
0.0081
0.0155
0.6528
8.00
11.90
4.696
119.28
0.1203
0.0112
0.0214
0.8997
11.50
17.11
4.560
115.82
0.1134
0.0105
0.0202
0.8484
13.00
19.34
4.494
114.15
0.1101
0.0102
0.0196
0.8240
15.00
22.32
4.408
111.96
0.1060
0.0099
0.0189
0.7928
18.00
26.78
4.276
108.61
0.0997
0.0093
0.0178
0.7460
20.30
30.21
4.184
106.27
0.0955
0.0089
0.0170
0.7142
20.80
30.95
4.156
105.56
0.0942
0.0088
0.0168
0.7047
21.00
31.25
4.154
105.51
0.0941
0.0087
0.0168
0.7040
23.20
34.52
4.044
102.72
0.0892
0.0083
0.0159
0.6672
24.20
36.01
4.000
101.60
0.0873
0.0081
0.0155
0.6528
8.50
12.65
4.944
125.58
0.1333
0.0124
0.0237
0.9973
10.00
14.88
4.886
124.10
0.1302
0.0121
0.0232
0.9740
13.00
19.34
4.768
121.11
0.1240
0.0115
0.0221
0.9275
16.00
23.81
4.648
118.06
0.1178
0.0110
0.0210
0.8814
9.00
13.39
5.192
131.88
0.1470
0.0137
0.0262
1.1000
13.00
19.34
5.044
128.12
0.1388
0.0129
0.0247
1.0380
14.00
20.83
5.012
127.30
0.1370
0.0127
0.0244
1.0249
15.00
22.32
4.974
126.34
0.1349
0.0125
0.0240
1.0094
15.50
23.06
4.950
125.73
0.1336
0.0124
0.0238
0.9997
17.00
25.30
4.892
124.26
0.1305
0.0121
0.0232
0.9764
20.00
29.76
4.778
121.36
0.1245
0.0116
0.0222
0.9314
23.00
34.22
4.670
118.62
0.1189
0.0111
0.0212
0.8898
25.00
37.20
4.580
116.33
0.1144
0.0106
0.0204
0.8558
26.00
38.69
4.548
115.52
0.1128
0.0105
0.0201
0.8439
14.00
20.83
5.290
134.37
0.1526
0.0142
0.0272
1.1418
17.00
25.30
5.190
131.83
0.1469
0.0137
0.0262
1.0990
19.50
29.02
5.090
129.29
0.1413
0.0131
0.0252
1.0571
20.00
29.76
5.090
129.29
0.1413
0.0131
0.0252
1.0571
22.50
33.48
4.990
126.75
0.1358
0.0126
0.0242
1.0159
25.20
37.50
4.890
124.21
0.1304
0.0121
0.0232
0.9756
1
m3/m
1
Gal/Ft
Appendix
Dimensions and Capacities of Casing (Continued)
OD
in.
mm
152
6
168
6-5/8
178
7
194
7-5/8
203
8
 Ft/Cu Ft =
 Ft/Bbl =
1
Cu Ft/Ft
1
Bbl/Ft
m/m3=
 Ft/Gal =
lb/ft
kg/m
10.50
12.00
ID
cu ft/ft n
m3/m l
bbl/ft 
gal/ft u
144.07
0.1755
0.0163
0.0313
1.3126
142.75
0.1723
0.0160
0.0307
1.2886
5.524
140.31
0.1664
0.0155
0.0296
1.2450
23.81
5.500
139.70
0.1650
0.0153
0.0294
1.2342
17.00
25.30
5.450
138.43
0.0620
0.0151
0.0289
1.2119
18.00
26.78
5.424
137.77
0.1605
0.0149
0.0286
1.2003
20.00
29.76
5.352
135.94
0.1562
0.0145
0.0278
1.1687
23.00
34.22
5.000
127.00
0.1364
0.0127
0.0243
1.1203
26.00
38.69
5.140
130.56
0.1441
0.0134
0.0257
1.0779
12.00
17.86
6.287
159.69
0.2156
0.0200
0.0384
1.6127
13.00
19.34
6.255
158.88
0.2134
0.0198
0.0380
1.5356
17.00
25.30
6.135
155.83
0.2053
0.0191
0.0366
1.4929
20.00
29.76
6.049
153.64
0.l996
0.0185
0.0355
1.4634
22.00
32.74
5.989
152.12
0.1956
0.0182
0.0348
1.4304
24.00
35.71
5.921
150.39
0.0912
0.0178
0.0341
1.4304
26.00
38.69
5.855
148.72
0.1870
0.0174
0.0333
1.3987
28.00
41.66
5.791
147.09
0.1829
0.0170
0.0326
1.3683
29.00
43.15
5.761
146.33
0.1810
0.0168
0.0322
1.3541
32.00
47.62
5.675
144.15
0.1756
0.0163
0.0313
1.3140
34.00
50.59
5.595
142.11
0.1707
0.0159
0.0304
1.2772
13.00
19.34
6.520
165.61
0.2319
0.0215
0.0413
1.8054
17.00
25.30
6.538
166.07
0.2331
0.0217
0.0415
1.7440
20.00
29.76
6.456
163.98
0.2273
0.0211
0.0405
1.7005
22.00
32.74
6.398
162.51
0.2233
0.0207
0.0398
1.6701
23.00
34.22
6.366
161.70
0.2210
0.0205
0.0394
1.6535
24.00
35.71
6.336
160.93
0.2190
0.0203
0.0390
1.6379
26.00
38.69
6.276
159.41
0.2148
0.0200
0.0383
1.6070
28.00
41.66
6.214
157.74
0.2106
0.0196
0.0375
1.5754
29.00
43.15
6.184
157.07
0.2086
0.0194
0.0371
1.5603
30.00
44.64
6.154
156.31
0.2066
0.0192
0.0368
1.5452
32.00
47.62
6.094
154.79
0.2025
0.0188
0.0361
1.5152
33.70
50.15
6.048
153.62
0.1995
0.0185
0.0355
1.4924
35.00
52.08
6.004
152.50
0.1966
0.0183
0.0350
1.4708
38.00
56.54
5.920
150.37
0.1911
0.0178
0.0340
1.4299
40.00
59.52
5.836
148.23
0.1858
0.0173
0.0331
1.3896
14.75
21.95
7.263
184.48
0.2877
0.0267
0.0512
2.1522
20.00
29.76
7.125
180.98
0.2769
0.0257
0.0493
2.0712
24.00
35.71
7.025
178.44
0.2692
0.0250
0.0479
2.0135
26.40
39.28
6.969
177.01
0.2649
0.0246
0.0472
1.9815
29.70
44.19
6.875
174.63
0.2578
0.0240
0.0459
1.9284
33.70
50.15
6.765
171.83
0.2496
0.0232
0.0445
1.8672
39.00
58.03
6.625
168.28
0.2394
0.0222
0.0426
1.7907
45.00
66.96
6.445
163.70
0.2265
0.0211
0.0404
1.6948
45.30
67.41
6.435
163.45
0.2258
0.0210
0.0402
1.6895
16.00
23.81
7.628
193.75
0.3173
0.0295
0.0565
2.3740
20.00
29.67
7.528
191.21
0.3091
0.0287
0.0550
2.3122
26.00
38.69
7.386
187.60
0.2975
0.0276
0.0530
2.2258
in.
mm
15.62
5.672
17.86
5.620
15.00
22.32
16.00
1
m3/m
1
Gal/Ft
149
Appendix
OD
in.
mm
206
8-1/8
219
8-5/8
229
9
244
9-5/8
254
10
273
10-3/4
279
11
 Ft/Cu Ft =
 Ft/Bbl =
150
1
Cu Ft/Ft
1
Bbl/Ft
m/m3=
 Ft/Gal =
lb/ft
kg/m
28.00
32.00
ID
cu ft/ft n
m3/m l
bbl/ft 
gal/ft u
190.12
0.3056
0.0284
0.0544
2.2858
187.58
0.2975
0.0276
0.0530
2.2252
7.285
185.04
0.2895
0.0269
0.0516
2.1653
48.78
7.185
182.50
0.2816
0.0262
0.0501
2.1063
42.00
62.50
7.125
180.98
0.2769
0.0257
0.0493
2.0712
20.00
29.75
8.191
208.05
0.3659
0.0340
0.0652
2.7374
24.00
35.71
8.097
205.66
0.3576
0.0332
0.0637
2.6749
28.00
41.66
8.017
203.63
0.3505
0.0326
0.0624
2.6223
32.00
47.62
7.921
201.19
0.3422
0.0318
0.0609
2.5599
36.00
53.57
7.825
198.76
0.3340
0.0310
0.0595
2.4982
38.00
56.54
7.775
197.79
0.3297
0.0306
0.0587
2.4664
40.00
59.52
7.725
196.22
0.3255
0.0302
0.0580
2.4348
43.00
63.98
7.651
194.34
0.3193
0.0297
0.0569
2.3883
44.00
65.47
7.625
193.68
0.3171
0.0295
0.0565
2.3721
48.00
71.42
7.537
191.44
0.3098
0.0288
0.0552
2.3177
49.00
71.92
7.511
190.78
0.3077
0.0286
0.0548
2.3017
34.00
50.59
8.290
210.57
0.3748
0.0348
0.0668
2.8039
38.00
56.54
8.196
208.18
0.3664
0.0340
0.0653
2.7407
40.00
59.52
8.150
207.01
0.3623
0.0337
0.0645
2.7100
45.00
66.96
8.032
204.01
0.3519
0.0327
0.0624
2.6321
50.20
74.70
7.910
200.91
0.3412
0.0317
0.0608
2.5528
55.00
81.84
7.812
198.42
0.3328
0.0309
0.0593
2.4899
29.30
43.60
9.063
230.20
0.4480
0.0416
0.0798
3.3512
32.30
48.06
9.001
228.63
0.4409
0.0411
0.0787
3.3055
36.00
53.57
8.921
226.59
0.4341
0.0403
0.0773
3.2470
40.00
59.52
8.835
224.41
0.4257
0.0396
0.0758
3.1847
43.50
64.73
8.755
222.38
0.4200
0.0390
0.0748
3.1273
47.00
69.94
8.681
220.50
0.4110
0.0382
0.0732
3.0747
53.50
79.61
8.535
216.79
0.3973
0.0369
0.0708
2.9721
58.40
86.90
8.435
214.25
0.3880
0.0361
0.0691
2.9029
61.10
90.92
8.375
212.73
0.3825
0.0355
0.0681
2.8617
71.80
106.84
8.125
206.38
0.3600
0.0335
0.0641
2.6934
33.00
49.10
9.384
238.35
0.4803
0.0446
0.0855
3.5928
41.50
61.75
9.200
233.68
0.4616
0.0429
0.0822
3.4533
45.50
67.70
9.120
231.65
0.4536
0.0421
0.0808
3.3935
50.50
75.14
9.016
229.01
0.4433
0.0412
0.0790
3.3166
55.50
82.58
8.908
226.26
0.4328
0.0402
0.0771
3.2376
61.20
91.07
8.690
223.37
0.4214
0.0392
0.0751
3.1524
32.75
48.73
10.192
258.88
0.5665
0.0526
0.1009
4.2382
35.75
53.20
10.136
257.45
0.5603
0.0521
0.0998
4.1917
40.50
60.26
10.050
255.27
0.5509
0.0512
0.0981
4.1209
45.50
67.70
9.950
252.73
0.5400
0.0502
0.0962
4.0393
51.00
75.89
9.850
250.19
0.5292
0.0492
0.0942
3.9585
54.00
80.35
9.784
248.51
0.5221
0.0485
0.0930
3.9056
55.00
81.84
9.760
247.90
0.5195
0.0483
0.0925
3.8865
60.70
90.32
9.660
245.36
0.5089
0.0473
0.0906
3.8073
65.70
97.76
9.560
242.82
0.4985
0.0463
0.0888
3.7289
71.10
105.80
9.450
240.03
0.4871
0.0453
0.0867
3.6435
26.75
39.80
10.552
268.02
0.6073
0.0564
0.1082
4.5429
in.
mm
41.66
7.485
47.62
7.385
35.50
52.82
39.50
1
m3/m
1
Gal/Ft
Appendix
OD
in.
mm
298
11-3/4
305
12
324
12-3/4
330
13
340
13-3/8
14
356
15
381
406
16
473
18-5/8
508
20
546
21-1/2
 Ft/Cu Ft =
 Ft/Bbl =
1
Cu Ft/Ft
1
Bbl/Ft
m/m3=
 Ft/Gal =
lb/ft
kg/m
38.00
42.00
ID
cu ft/ft n
m3/m l
bbl/ft 
gal/ft u
283.21
0.6781
0.0630
0.1208
5.0724
281.53
0.6701
0.0623
0.1193
5.0125
11.000
279.40
0.6599
0.0613
0.1175
4.9368
80.35
10.880
276.35
0.6456
0.0600
0.1150
4.8297
60.00
89.28
10.772
273.61
0.6329
0.0588
0.1127
4.7343
65.00
96.72
10.682
271.32
0.6223
0.0578
0.1108
4.6555
31.50
46.87
11.514
292.46
0.7230
0.0672
0.1288
5.4089
in.
mm
56.54
11.150
62.50
11.084
47.00
69.94
54.00
40.00
59.52
11.384
289.15
0.7068
0.0657
0.1259
5.2875
43.00
63.98
12.130
308.10
0.8025
0.0746
0.1429
6.0032
53.00
78.86
11.970
304.04
0.7815
0.0726
0.1392
5.8459
36.50
54.31
12.482
317.04
0.8497
0.0789
0.1513
6.3567
40.00
59.52
12.438
315.93
0.8438
0.0784
0.1503
6.3119
45.00
66.96
12.360
313.94
0.8332
0.0774
0.1484
6.2330
50.00
74.40
12.282
311.96
0.8227
0.0764
0.1465
6.1546
54.00
80.35
12.220
310.39
0.8144
0.0757
0.1451
6.0926
48.00
71.42
12.715
322.96
0.8818
0.0819
0.1570
6.5962
54.50
81.10
12.615
320.42
0.8679
0.0816
0.1546
6.4928
61.00
90.77
12.515
317.88
0.8542
0.0794
0.1521
6.3903
68.00
101.18
12.415
315.34
0.8406
0.0781
0.1497
6.2866
72.00
107.14
12.347
313.61
0.8315
0.0772
0.1481
6.2199
77.00
114.58
12.275
311.79
0.8218
0.0764
0.1464
6.1476
83.00
123.50
12.175
309.25
0.8084
0.0751
0.1440
6.0478
85.00
126.48
12.159
308.84
0.8063
0.0749
0.1436
6.0319
92.00
136.90
12.031
305.59
0.7894
0.0733
0.1406
5.9056
98.00
145.82
11.937
303.20
0.7772
0.0722
0.1384
5.8137
42.00
74.40
13.488
338.94
0.9863
0.0902
0.1757
7.3786
50.00
74.40
13.344
338.94
0.9712
0.0902
0.1730
7.2649
47.50
70.68
14.418
366.22
1.1338
0.1053
0.2019
8.4815
52.50
78.12
15.396
391.06
1.2928
0.1201
0.2303
9.6711
55.00
81.84
15.375
390.53
1.2893
0.1198
0.2296
9.6447
65.00
96.72
15.250
387.35
1.2684
0.1178
0.2259
9.4886
70.00
104.16
15.198
386.03
1.2598
0.1170
0.2244
9.4240
75.00
111.60
15.125
384.18
1.2477
0.1159
1.2222
9.3336
84.00
124.99
15.010
381.25
1.2288
0.1142
0.2189
9.1922
109.00
162.19
14.688
373.08
1.1766
0.1093
0.2096
8.8021
78.00
116.06
17.855
453.52
1.7387
0.1615
0.3097
13.0071
87.50
130.20
17.755
450.98
1.7193
0.1597
0.3062
12.8618
96.50
143.59
17.655
448.44
1.7000
0.1579
0.3028
12.7173
90.00
133.92
19.166
486.82
2.0034
0.1861
0.3568
14.9873
94.00
139.87
19.124
485.75
1.9947
0.1853
0.3553
14.9217
106.50
158.47
19.000
482.60
1.9689
0.1829
0.3507
14.7288
133.00
197.90
18.730
475.74
1.9133
0.1778
0.3408
14.3132
92.50
137.64
20.710
526.03
2.3392
0.2173
0.4166
17.4993
103.00
153.26
20.610
523.49
2.3167
0.2152
0.4126
17.3307
114.00
169.63
20.510
520.95
2.2943
0.2132
0.4086
17.1630
1
m3/m
1
Gal/Ft
151
Appendix
Dimensions and Capacities of Drillpipe
OD
in.
mm
2-3/8
60
73
2-7/8
89
3-1/2
102
4
114
4-1/2
127
5
140
5-1/2
141
5-9/16
kg/m
4.80
4.85
ID
cu ft/ft n
m3/m l
bbl/ft 
gal/ft u
50.8
0.02182
0.0020
0.00389
0.16320
50.7
0.02171
0.0020
0.00387
0.16239
1.815
46.1
0.01797
0.0017
0.00320
0.13440
9.60
2.469
62.7
0.03325
0.0031
0.00592
0.24872
6.85
10.20
2.441
62.0
0.03250
0.0030
0.00579
0.24311
8.35
12.42
2.323
59.0
0.02943
0.0027
0.00524
0.22017
10.40
15.48
2.151
54.6
0.02523
0.0023
0.00449
0.18877
8.50
12.65
3.063
77.8
0.05117
0.0047
0.00911
0.38278
in.
mm
7.14
2.000
7.22
1.995
6.65
9.90
6.45
9.50
14.14
2.992
76.0
0.04882
0.0045
0.00870
0.36524
11.20
16.67
2.900
73.7
0.04587
0.0043
0.00817
0.34313
13.30
19.79
2.764
70.2
0.04167
0.0039
0.00742
0.31170
15.50
23.06
2.602
66.1
0.03693
0.0034
0.00658
0.27623
10.40
15.48
3.500
88.9
0.06681
0.0062
0.01190
0.49980
11.85
17.63
3.476
88.3
0.06590
0.0061
0.01174
0.49297
12.50
18.60
3.382
85.9
0.06238
0.0058
0.01111
0.46667
14.00
20.83
3.340
84.8
0.06084
0.0057
0.01084
0.45515
15.70
23.36
3.240
82.3
0.05725
0.0053
0.01020
0.42830
12.75
18.97
4.000
101.6
0.08726
0.0081
0.01554
0.65280
13.75
20.46
3.958
100.5
0.08544
0.0069
0.01522
0.63916
16.60
24.70
3.826
97.2
0.07984
0.0074
0.01422
0.59724
18.10
26.93
3.754
95.4
0.07686
0.0071
0.01369
0.57497
20.00
29.76
3.640
92.5
0.07226
0.0067
0.01287
0.54058
16.25
24.18
4.408
112.0
0.10597
0.0098
0.01887
0.79276
19.50
29.02
4.276
108.6
0.09972
0.0093
0.01776
0.74599
25.60
38.09
4.000
101.6
0.08726
0.0081
0.01554
0.65280
21.90
32.59
4.778
121.4
0.12451
0.0116
0.02218
0.93143
24.70
36.75
4.670
118.6
0.11895
0.0111
0.02119
0.88980
19.00
28.27
4.975
126.4
0.13499
0.0125
0.02404
1.00983
22.20
33.03
4.859
123.4
0.12877
0.0120
0.02293
0.96328
25.25
37.57
4.733
120.2
0.12218
0.0113
0.02176
1.50080
22.20
33.03
6.065
154.1
0.20062
0.0186
0.03573
1.50080
37.50
5.965
151.5
0.19406
0.0180
0.03456
1.45171
6-5/8
168
25.20
31.90
47.47
5.761
146.3
0.18101
0.0169
0.03224
1.35412
7-5/8
194
29.25
43.52
6.969
177.0
0.26488
0.0246
0.04718
1.98153
8-5/8
219
40.00
59.52
7.825
198.8
0.33395
0.0310
0.05948
2.49821
 Ft/Cu Ft =
 Ft/Bbl =
152
lb/ft
1
Cu Ft/Ft
1
Bbl/Ft
m/m3=
 Ft/Gal =
1
m3/m
1
Gal/Ft
Appendix
Dimensions and Capacities of Tubing
OD
in.
mm
lb/ft
kg/m
ID
in.
mm
cu ft/ft n
m3/m l
bbl/ft 
gal/ft u
0.02770
1.050 Reg
27 Reg
1.14
1.70
0.824
20.93
0.00370
0.0003
0.00066
1.050 EUE
27 EUE
1.20
1.79
0.824
20.93
0.00370
0.0003
0.00066
0.02770
1.20
1.79
0.824
20.93
0.00370
0.0003
0.00066
0.02770
1.050
27
1.315 Reg
33 Reg
1.315 EUE
33 EUE
1.50
2.23
0.742
18.85
0.00300
0.0002
0.00053
0.02246
1.70
2.53
1.049
26.64
0.00600
0.0006
0.00107
0.04490
1.80
2.68
1.049
26.64
0.00600
0.0006
0.00107
0.04490
2.25
3.35
0.957
24.31
0.00500
0.0005
0.00089
0.03737
2.25
3.35
0.957
24.31
0.00500
0.0005
0.00089
0.03737
42
2.10
3.13
1.410
35.81
0.01084
0.0010
0.00193
0.08111
1.660 Reg
42 Reg
2.30
3.42
1.380
30.05
0.01039
0.0010
0.00185
0.07770
1.660 EUE
42 EUE
2.40
3.57
1.380
30.05
0.01039
0.0010
0.00185
0.07770
1.660
42
3.02
4.49
1.278
32.46
0.00891
0.0008
0.00159
0.06664
1.660
1.900
48
2.40
3.57
1.650
41.91
0.01485
0.0014
0.00264
0.11108
1.900 Reg
48 Reg
2.75
4.09
1.610
40.89
0.01414
0.0013
0.00252
0.10576
1.900 EUE
48 EUE
2.90
4.32
1.610
40.89
0.01414
0.0013
0.00252
0.10576
1.900
48
3.64
5.42
1.500
38.10
0.01227
0.0011
0.00219
0.09180
2.063
52
3.25
4.84
1.751
44.74
0.01672
0.0016
0.00298
0.12509
2.375 Reg
60 Reg
4.00
5.95
2.041
51.84
0.02272
0.0021
0.00405
0.16996
2.375 EUE
60 EUE
4.10
6.10
2.041
51.84
0.02272
0.0021
0.00405
0.16996
2.375 Reg
60 Reg
4.60
6.84
1.995
50.67
0.02171
0.0020
0.00387
0.16239
2.375 EUE
60 EUE
4.70
6.99
1.995
50.67
0.02171
0.0020
0.00387
0.16239
2.375 Reg
60 Reg
5.00
7.44
1.947
49.95
0.02068
0.0019
0.00368
0.15467
2.375
60
5.30
7.89
1.939
49.25
0.02051
0.0019
0.00365
0.15340
2.375 Reg
60 Reg
5.80
8.63
1.867
47.42
0.01901
0.0018
0.00339
0.14222
2.375 EUE
60 EUE
5.95
8.85
1.867
47.42
0.01901
0.0018
0.00339
0.14222
6.20
9.23
1.853
47.07
0.01873
0.0017
0.00334
0.14009
7.70
11.46
1.703
43.26
0.01582
0.0015
0.00282
0.11833
5.90
8.78
2.469
62.71
0.03325
0.0031
0.00592
0.24872
60
2.375
2.875 Reg
73 Reg
6.40
9.52
2.441
62.00
0.03250
0.0030
0.00579
0.24311
2.875 EUE
73 EUE
6.50
9.67
2.441
62.00
0.03250
0.0030
0.00579
0.24311
2.875
73
7.9O
11.76
2.323
59.00
0.02943
0.0027
0.00524
0.22017
2.875 Reg
73 Reg
8.60
12.80
2.259
57.38
0.02783
0.0026
0.00496
0.20821
2.875 EUE
73 EUE
8.70
12.95
2.259
57.38
0.02783
0.0026
0.00496
0.20821
9.50
14.14
2.195
55.75
0.02628
0.0024
0.00468
0.19658
10.70
15.92
2.091
53.11
0.02385
0.0022
0.00425
0.17839
11.00
16.36
2.065
52.45
0.02326
0.0022
0.00414
0.17398
7.70
11.46
3.068
77.93
0.05134
0.0048
0.00914
0.38400
73
2.875
3.500 Reg
89 Reg
8.50
12.65
3.068
77.93
0.05134
0.0048
0.00914
0.38400
3.500 EUE
89 EUE
8.50
13.24
3.018
76.66
0.04968
0.0046
0.00885
0.37162
3.500 Reg
89 Reg
9.20
13.69
2.992
76.00
0.04882
0.0045
0.00870
0.36524
3.500 EUE
89 EUE
9.30
13.83
2.992
76.00
0.04882
0.0045
0.00870
0.36524
10.20
15.18
2.797
71.04
0.04657
0.0043
0.00829
0.36524
12.70
18.90
2.750
69.85
0.04125
0.0038
0.00735
0.30855
12.80
19.05
2.764
70.21
0.04167
0.0039
0.00742
0.30855
3.500 Reg
89 Reg
3.500
89 Reg
3.500 EUE
89 EUE
89
3.500
12.95
19.27
2.750
69.85
0.04125
0.0038
0.00735
0.30855
14.90
22.17
2.602
66.09
0.03693
0.0034
0.00658
0.27623
15.80
23.57
2.548
64.72
0.03541
0.0033
0.00631
0.26489
16.70
24.85
2.480
62.99
0.03354
0.0031
0.00597
0.25143
4.000 Reg
102 Reg
9.25
13.76
3.548
90.12
0.06866
0.0064
0.01223
0.51360
4.000 EUE
102 EUE
9.50
14.14
3.548
86.94
0.06866
0.0064
0.01223
0.51360
 Ft/Cu Ft =
 Ft/Bbl =
1
Cu Ft/Ft
1
Bbl/Ft
m/m3=
 Ft/Gal =
1
m3/m
1
Gal/Ft
153
Appendix
Dimensions and Capacities of Tubing (Continued)
OD
in.
mm
4.000
102
114 Reg
4.500 Reg
4.500 EUE
114 EUE
4.500
114
lb/ft
kg/m
11.00
11.60
ID
cu ft/ft n
m3/m l
bbl/ft 
gal/ft u
88.29
0.06590
0.0061
0.01174
0.49297
87.07
0.06409
0.0060
0.01142
0.47945
3.340
84.84
0.06084
0.0057
0.01084
0.45515
16.37
4.026
102.26
0.08840
0.0082
0.01575
0.66131
11.80
17.56
3.990
101.35
0.08683
0.0081
0.01546
0.64954
12.60
18.75
3.958
100.53
0.08544
0.0079
0.01522
0.63916
12.75
18.97
3.958
100.53
0.08544
0.0079
0.01522
0.63916
13.50
20.08
3.920
99.56
0.08381
0.0078
0.01493
0.62695
15.50
23.06
3.826
97.18
0.07984
0.0074
0.01422
0.59724
19.20
28.57
3.640
92.46
0.07226
0.0067
0.01287
0.54058
in.
mm
16.37
3.476
17.26
3.428
13.40
19.94
11.00
Dimensions and Capacities of Tubing
3/4
19.05
-
-
0.652
16.56
0.00230
0.000215
0.000410
0.0172
1
25.4
-
-
0.870
22.10
0.00413
0.000384
0.000736
0.0309
 Ft/Cu Ft =
 Ft/Bbl =
154
1
Cu Ft/Ft
1
Bbl/Ft
m/m3=
 Ft/Gal =
1
m3/m
1
Gal/Ft
Appendix
Formulas for Contents of Pipe Lines
Barrels/lin ft
=
Lin ft/barrel
=
Gal/lin ft
=
Lin ft/gal
=
Cu ft/lin ft
=
Lin ft/cu ft
=
.0009714 x D2
1029.4
D2
.0408 x D2
24.51
D2
.005454 x D2
183.35
D2
D
=
Diameter in inches
Cu m/lin m
=
0.00007854 (D2)
D = Diameter in cm
Formulas for Capacity of Vertical Cylindrical Tanks with Flat Ends
Bbl/ft of depth of fluid
=
.1400 x D2 (ft)
Bbl/in. of depth of fluid
=
.01165 x D2 (ft)
Gal/ft of depth of fluid
=
5.8752 x D2 (ft)
Gal/in. of depth of fluid
=
.4896 x D2 (ft)
Cu ft/ft of depth of fluid
=
.7854 x D2 (ft)
Cu ft/in. of depth of fluid
=
.06545 x D2 (ft)
D
=
Diameter in feet
Cu m/m of depth
=
.7854 x D2 (m)
Cu m/cm of depth
=
.007854 D2 (m)
D = Diameter in meters
Formulas for Capacity of Rectangular Tanks with Flat Ends
For small or medium size rectangular tanks or pits measure the length and width in inches.
=
.0001031 x L (in.) x W (in.)
=
.004329 x L (in.) x W (in.)
=
.0005787 x L (in.) x W (in.)
=
.000001 x L (cm) x W (cm)
L = Length in inches
Cu m/cm of depth
W = Width in inches
L = Length in centimeters
W = Width in centimeters
For large tanks or pits measure length and width in feet.
=
.01484 x L (ft) x W (ft)
=
.6234 x L (ft) x W (ft)
=
.08333 x L (ft) x W (ft)
Cu m/cm of depth
=
.01 L (m) x W (m)
L = Length in meters
W = Width in meters
155
Appendix
Using a Table to Calculate Amount of
Fluid in a Horizontal Cylindrical Tank
The drawing below illustrates a horizontal cylindrical tank,
12 ft (3.66 m) in diameter and 20 ft (3.10 m) long. The formula to
calculate the volume of your 2 ft (0.61 m) of fluid is very complex,
so we will use the Table. The computation involves four parts:
20 ft (3.10m)
12 ft (3.66m)
2 ft (0.61m)
a. Calculate total volume of the tank.
Total Volume, Barrels = 0.14 x D2 x L
= 0.14 x 122 x 20
= 403.2 barrels
Total Volume, m3 = 0.7854 D2 x L
= .7854 (3.662) (6.10)
= 64.18 m3
b. Calculate “Dec % Fluid Ht.” (decimal percent fluid height) for your 2 ft fluid level.
(If your tank is 1/2 full, the value is 0.50; if it is completely full, the value is 1.0.)
Dec. Fluid Ht = Fluid Height/Total Height = 2/12 = 0.167
Dec. Fluid Ht =
0.61 m
3.66 m
= 0.167
c. Find the coefficient (multiplier) from the table:
Coefficient = 0.109869
d. To get your volume of fluid for the 2 feet (partial volume), multiply the coefficient x total tank volume:
Partial Volume = 0.109869 x 403.2
= 44.3 barrels
156
Partial Volume = 0.109869 x 64.18 m3
= 7.05 m3
Appendix
Coefficients for Partial Volumes of Horizontal Cylinders
Dec %Fl Ht
0
1
2
3
4
5
6
7
8
9
.00
.000000
.000053
.000151
.000279
.000429
.000600
.000788
.000992
.001212
.001445
.01
.001692
.001952
.002223
.002507
.002800
.003104
.003419
.003743
.004077
.004421
.02
.004773
.004134
.005503
.005881
.006267
.006660
.007061
.007470
.007886
.008310
.03
.008742
.009179
.009625
.010076
.010534
.010999
.011470
.011947
.012432
.012920
.04
.013417
.013919
.014427
.014940
.015459
.015985
.016515
.017052
.017593
.018141
.05
.018692
.019250
.019813
.020382
.020955
.021533
.022115
.022703
.023296
.023894
.06
.024496
.025103
.025715
.026331
.026952
.027578
.028208
.028842
.029481
.030124
.07
.030772
.031424
.032081
.032740
.033405
.034073
.034747
.035423
.036104
.036789
.08
.037478
.038171
.038867
.039569
.040273
.040981
.041694
.042410
.043129
.043852
.09
.044579
.045310
.046043
.046782
.047523
.048268
.049017
.049768
.050524
.051283
.10
.052044
.052810
.053579
.054351
.055126
.055905
.056688
.057474
.058262
.059054
.11
.059850
.060648
.061449
.062253
.063062
.063872
.064687
.065503
.066323
.067147
.12
.067972
.068802
.069633
.070469
.071307
.072147
.072991
.073836
.074686
.075539
.13
.076393
.077251
.078112
.078975
.079841
.080709
.081581
.082456
.083332
.084212
.14
.085094
.085979
.086866
.087756
.088650
.089545
.090443
.091343
.092246
.093153
.15
.094061
.094971
.095884
.096799
.097717
.098638
.099560
.100486
.101414
.102343
.16
.103275
.104211
.105147
.106087
.107029
.107973
.108920
.109869
.110820
.111773
.17
.112728
.113686
.114646
.115607
.116572
.117538
.118506
.119477
.120450
.121425
.18
.122403
.123382
.124364
.125347
.126333
.127321
.128310
.129302
.130296
.131292
.19
.132290
.133291
.134292
.135296
.136302
.137310
.138320
.139332
.140345
.141361
.20
.142378
.143398
.144419
.145443
.146468
.147494
.148524
.149554
.150587
.151622
.21
.152659
.153697
.154737
.155779
.156822
.157867
.158915
.159963
.161013
.162066
.22
.163120
.164176
.165233
.166292
.167353
.168416
.169480
.170546
.171613
.172682
.23
.173753
.174825
.175900
.176976
.178053
.179131
.180212
.181294
.182378
.183463
.24
.184550
.185639
.186729
.187820
.188912
.190007
.191102
.192200
.193299
.194400
.25
.195501
.196604
.197709
.198814
.199922
.201031
.202141
.203253
.204368
.205483
.26
.206600
.207718
.208837
.209956
.211079
.212202
.213326
.214453
.215580
.216708
.27
.217839
.218970
.220102
.221235
.222371
.223507
.224645
.225783
.226924
.228065
.28
.229209
.230352
.231498
.232644
.233791
.234941
.236091
.237242
.238395
.239548
.29
.240703
.241859
.243016
.244173
.245333
.246494
.247655
.248819
.249983
.251148
.30
.252315
.253483
.254652
.255822
.256992
.258165
.259338
.260512
.261687
.262863
.31
.264039
.265218
.266397
.267578
.268700
.269942
.271126
.272310
.273495
.274682
.32
.275869
.277058
.278247
.279437
.280627
.281820
.283013
.284207
.285401
.286598
.33
.287795
.288992
.290191
.291390
.292591
.293793
.294995
.296198
.297403
.298605
.34
.299814
.301021
.302228
.303438
.304646
.305857
.307068
.308280
.309492
.310705
.35
.311918
.313134
.314350
.315566
.316783
.318001
.319219
.320439
.321660
.322881
.36
.324104
.325326
.326550
.327774
.328999
.330225
.331451
.332678
.333905
.335134
.37
.336363
.337593
.338823
.340054
.341286
.342519
.343751
.344985
.346220
.347455
.38
.348690
.349926
.351164
.352402
.353640
.351879
.356119
.357350
.358599
.359840
.40
.373530
.374778
.376026
.377275
.378524
.379774
.331024
.382274
.383526
.384778
.41
.386030
.387283
.388537
.389790
.391044
.392298
.393553
.394808
.396063
.397320
.42
.398577
.399834
.401092
.402350
.403608
.404866
.406125
.407384
.408645
.409904
.43
.411165
.412426
.413687
.414949
.416211
.417473
.418736
.419998
.421261
.422525
.44
.423788
.425052
.426316
.4 7582
.4 8846
.430112
.431378
.432645
.433911
.435178
.45
.436445
.437712
.438979
.440246
.441544
.442782
.444050
.445318
.446587
.447857
.46
.449125
.450394
.451663
.452932
.454201
.455472
.456741
.458012
.459283
.460554
.47
.461825
.463096
.464367
.465038
.466910
.468182
.469453
.470725
.471997
.473269
.48
.474541
.475814
.477086
.478358
.479631
.480903
.482176
.483449
.484722
.485995
.49
.487269
.488542
.489814
.491087
.492360
.493633
.494906
.496179
.497452
.498726
.50
.50000
.501274
.502548
.503821
.505094
.506367
.507640
.508913
.510186
.511458
.51
.512731
.514005
.515278
.516551
.517824
.519097
.520369
.521642
.522914
.524186
.52
.525459
.526731
.528003
.529275
.530547
.531818
.533090
.534362
.535633
.536904
.53
.538175
.539446
.540717
.541988
.543259
.544528
.545799
.547068
.548337
.549606
.54
.550875
.552143
.553413
.554682
.555950
.557218
.558486
.559754
.561021
.562288
.55
.563555
.564822
.566089
.567355
.568622
.569888
.571154
.572418
.573684
.574948
.56
.576212
.577475
.578739
.530002
.581264
.482527
.583789
.585051
.586313
.587574
.57
.588835
.590096
.591355
.592616
.593875
.595134
.596392
.597650
.598008
.600166
.58
.610423
.602680
.603937
.605192
.606447
.607702
.608956
.610210
.611463
.612717
157
Appendix
Coefficients for Partial Volumes of Horizontal Cylinders (Continued)
158
Dec %Fl Ht
0
1
2
3
4
5
6
7
8
9
.59
.613970
.615222
.616474
.617726
.618976
.620226
.621476
.622725
.623974
.625222
.60
.626470
.627718
.628964
.630210
.631455
.632700
.633944
.635189
.636432
.637675
.61
.638918
.640160
.641401
.642641
.643881
.645121
.646360
.647598
.648836
.650074
.62
.651310
.652545
.653780
.655015
.656249
.657481
.658714
.659946
.661177
.662407
.63
.663637
.664866
.666095
.667322
.668540
.669775
.671001
.672226
.673450
.674674
.64
.675896
.677119
.678340
.679561
.680781
.681999
.683217
.684434
.685650
.686866
.65
.688082
.689295
.690508
.691720
.692032
.694143
.695354
.696562
.697772
.698979
.66
.700186
.701392
.702597
.703802
.705005
.706207
.707409
.708610
.709809
.711008
.67
.712205
.713402
.714599
.715793
.716987
.718180
.719373
.720563
.721753
.722942
.68
.724131
.725318
.726505
.727690
.728874
.730058
.731240
.732422
.733603
.734782
.69
.735961
.737137
.738313
.739488
.740662
.741835
.743008
.744178
.745348
.746517
.70
.747685
.748852
.750017
.751181
.752345
.753506
.754667
.755827
.756984
.758141
.71
.759297
.760452
.761605
.762758
.763909
.765059
.766209
.767356
.768502
.769648
.72
.770791
.771935
.773076
.774217
.775355
.776493
.777629
.778765
.779898
.781030
.73
.782161
.783292
.784420
.785547
.786674
.787798
.788921
.790043
.791163
.792282
.74
.793400
.794517
.795632
.796747
.797859
.798960
.800078
.801186
.802291
.803396
.75
.804499
.805600
.806701
.807800
.808898
.809993
.811088
.812180
.813271
.814361
.76
.815450
.816537
.817622
.818706
.819788
.820869
.821947
.823024
.824100
.825175
.77
.826247
.827318
.828387
.829454
.830520
.831584
.832647
.833708
.834767
.835824
.78
.836880
.837934
.838987
.840037
.841085
.842133
.843178
.844221
.845263
.846303
.79
.847341
.848378
.849413
.850446
.851476
.852506
.853532
.854557
.855581
.856602
.80
.857622
.858639
.859655
.860668
.861680
.862690
.863698
.864704
.865708
.866709
.81
.867710
.868708
.869704
.870698
.871690
.872679
.873667
.874653
.875636
.876618
.82
.877597
.878575
.879550
.880523
.881494
.882462
.883428
.884393
.885354
.886314
.83
.887272
.888227
.889180
.890131
.891080
.892027
.892971
.893913
.894853
.895789
.84
.896725
.897657
.898596
.899514
.900440
.901362
.902283
.903201
.904116
.905029
.85
.905939
.906847
.907754
.908657
.909557
.910455
.911350
.912244
.913134
.914021
.86
.914906
.915788
.916668
.917544
.918419
.919291
.920159
.921025
.921888
.922749
.87
.923607
.924461
.925314
.926164
.927009
.927853
.928693
.929531
.930367
.931198
.88
.932028
.932853
.933677
.934497
.935313
.936128
.936938
.937747
.938551
.939352
.89
.940150
.940946
.941738
.942526
.943312
.944095
.944874
.945619
.946421
.947190
.90
.947956
.948717
.949476
.950232
.950983
.951732
.952477
.953218
.953957
.954690
.91
.955421
.956148
.956871
.957590
.958306
.959019
.959727
.960431
.961133
.961829
.92
.962522
.963211
.963896
.964577
.965253
.965927
.966595
.967260
.967919
.968576
.93
.969228
.969876
.970519
.971158
.971792
.972422
.973048
.973669
.974285
.974897
.94
.975504
.976106
.976704
.977297
.977885
.978467
.979045
.979618
.980187
.980750
.95
.981308
.981859
.982407
.982948
.983485
.984015
.984854
.985060
.985573
.986081
.96
.986583
.987080
.987568
.988053
.988530
.989001
.989166
.989924
.990375
.990821
.97
.991258
.991690
.992114
.992530
.992939
.993340
.993733
.994119
.994497
.994866
.98
.995227
.995579
.995923
.996257
.996581
.996896
.997200
.997493
.997777
.998048
.99
.998308
.998555
.998788
.999008
.999212
.999400
.999571
.999721
.999849
.999947
1.00
1.00000
-
-
-
-
-
-
-
-
-
Appendix
Tubing Movement Formulas
Changes in temperature and pressure cause contraction or expansion of a tubing string as covered in
detail within Baker’s “Packer Calculation Handbook”. For ready reference, the formulas for calculating
the forces developed by this contraction/expansion are given below:
F1
(piston effect) = (Ap - Ai) D Pi - (Ap - Ao) D Po
F2
(buckling effect) = usually negligible
F3
(ballooning effect) = .6 (D Pia Ai - D Poa Ao)
F4 (temperature effect) = 207 As D t
The above forces are in pounds and the equivalent tubing movement can be obtained from the stretch
charts in another section of this handbook or can be calculated using the formula:
D L (stretch or contraction in feet) =
Where: F = force in pounds
L = tubing length in feet
E = elasticity factor of steel = 30,000,000
As
= cross section area of tubing in square inches
Terms used in the force formulas are defined below:
As = cross section area of tubing in square inches = Ao - Ai
Ap = area of packer bore in square inches
Ao
= area of tubing OD in square inches
Ai
= area of tubing ID in square inches
D Pi =
change in tubing pressure at packer in pounds per square inch
D Po =
change in annulus pressure at packer in pounds per square inch
D Pia = change in average tubing pressure in pounds per square inch
D Poa = change in average annulus pressure in pounds per square inch
D t =
change in average tubing temperature in degrees Fahrenheit
For more detailed information regarding tubing movement refer to the Baker “Packer Calculation Handbook.”
159
Appendix
Stretch Tables
Tubing Stretch Table
Drillpipe Stretch Table
OD
Weight
ID
Wall Area
Stretch
Constant
in.
lb/ft
in.
sq in.
in./1,000 lb/
1,000 ft
4.36
2.579
1.268
0.31546
3170.0
4.64
2.563
1.333
0.30008
3332.5
2.441
1.812
0.22075
4530.0
2.323
2.254
0.17746
5635.0
6.40
6.50
7.90
2.875
(2-7/8)
8.60
8.70
8.90
2.259
2.484
0.16103
6210.0
2.243
2.540
0.15748
6350.0
Stretch
Constant
in.
lb/ft
in.
sq in.
in./1,000
lb/1,000 ft
(2-3/8)
(2-7/8)
(3-1/2)
(4)
Free Point
Constant
4.85
1.995
1.304
0.30675
3260.0
6.65
1.815
1.843
0.21704
4607.5
6.85
2.441
1.812
0.22075
4530.0
10.40
2.151
2.858
0.13996
7145.0
9.50
2.992
2.590
0.15444
6475.0
13.30
2.764
3.621
0.11047
9052.5
15.50
2.602
4.304
0.09294
10760.0
11.85
3.476
3.077
0.13000
7692.5
9512.5
2.195
2.708
0.14771
6770.0
14.00
3.340
3.805
0.10512
2.858
0.13996
7145.0
13.75
3.958
3.600
0.11111
9000.0
11.00
2.065
3.143
0.12727
7857.5
16.60
3.826
4.407
0.09076
11017.5
11.65
1.995
3.366
0.11884
8415.0
18.10
3.754
4.836
0.08271
12090.0
3.188
1.639
0.24405
4097.5
20.00
3.640
5.498
0.07275
13745.0
16.25
4.408
4.374
0.09145
10935.0
3.068
2.228
0.17953
5570.0
19.50
4.276
5.275
0.07583
13187.5
2.992
2.590
0.15444
6475.0
21.90
4.778
5.828
0.06863
14570.0
24.70
4.670
6.630
0.06033
16575.0
25.20
5.965
6.526
0.06129
16315.0
9.20
9.30
10.20
10.30
2.922
2.915
0.13722
7287.5
12.80
2.764
3.621
0.11047
9052.5
12.95
2.750
3.682
0.10864
9205.0
13.70
2.673
4.010
0.09975
10025.0
14.70
2.601
4.308
0.09285
10770.0
15.10
2.602
4.304
0.09294
10760.0
15.80
2.524
4.618
0.08662
11545.0
17.05
2.440
4.945
0.08089
12362.5
3.548
2.680
0.14925
6700.0
3.476
3.077
0.13000
7692.5
9.40
9.50
10.80
10.90
11.00
11.60
3.428
3.337
0.11987
8342.5
13.40
3.340
3.805
0.10512
9512.5
3.958
3.600
0.11111
9000.0
3.826
4.407
0.09076
11017.5
12.60
12.75
160
Wall Area
2.151
7.70
4.500
(4-1/2)
ID
9.50
5.63
4.000 (4)
Nominal
Weight
10.40
5.75
3.500
(3-1/2)
Free Point
Constant
OD
15.10
15.50
16.90
3.754
4.836
0.08271
12090.0
19.20
3.640
5.498
0.07275
13745.0
(4-1/2)
(5)
(5-1/2)
(6-5/8)
Notes
Accufrac™ is a trademark of Stewart and Stevenson Services, Inc.; Aflas® is a registered trademark of Ashai Glass Company, Ltd.; AutoCad® is a registered
trademark of Autodesk, Inc.; Bowen® is a registered trademark of National Oilwell L.P.; GFI™ is a registered trademarkof Greg Filtration, Inc.; Hallestoy® is a
registered trademark of Haynes International, Inc.; Intel® Pentium® is a registered trademark of Intel Corporation in the U.S. and other countries.; Mara-StimSM is
a service mark of Marathon Oil Company.; MS-DOS® is a registered trademarkof Microsoft Corporation in the United States and/or other countries.; Pentium® is a
registered trademark of Intel Corporation in the U.S.and other countries.; PulsFrac™ is a trademark of John F. Schatz Research and Consulting, Inc.; StimGun™ is a
trademark of Marathon Oil Company.; Teflon® is registered trademark of E.I. Dupont; Viton® is registered trademark of E.I. Dupont.; Windows NT® is a registered
trademark of Microsoft Corporation in the United States and/or other countries.
161
162
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.
www.bakerhughes.com
© 2010 Baker Hughes Incorporated. All rights reserved. 30264T

Sand Control Systems

Transcription

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