Table of Contents
BHA Drilling ToolsBorrox AP Advanced Performance Sealed-Bearing Reamer Model 60 and 62 Rotary Reamer
Shock Sub
Diamond-Enhanced Insert Reamer Inline Reamer
Gauge-Indicator Sub
DOG Drilling On Gauge Sub Diamond-Enhanced Insert Stabilizer
Double-Diamond Combo Tool
Integral Blade Stabilizer
Ezy-Change Type II Rig-Replaceable Sleeve-Type Stabilizer Neyrfor Traditional
Neyrfor Delta
Neyrfor LC3 Turbodrill Locking Clutch
Drilling Impact Tools
AP Impact System
Jar-Pact Program
Data Acquisition Program
Hydra-Jar AP
Accelerator AP
HydraQuaker
Hydra-TT Double-Acting Hydraulic Jar Accelerator-TT Double-Acting Accelerator Tool
Hydra-Stroke Bumper Sub
TMC Jar, Single-Acting Hydraulic Fishing Jar (Up Only) TMC Accelerator, Single-Acting Fishing Accelerator (Up Only) TMC Bumper Fishing Bumper Sub
Hex Fishing Bumper Sub
Borehole Enlargement
Borehole Enlargement Introduction
Rhino XC Reamer
Rhino XS Reamer
Predator Cutter Blocks
Cement Cleanout Blocks
Drilling Tools Catalog
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The Borrox AP* advanced performance sealed-bearing reamer has the flexibility and durability to meet rigorous downhole demands. Hole gauge maintenance and torque reduction characteristics can be customized with the Borrox AP reamer.
To help operators take on different formation applications, the Borrox AP reamer works with three different cutter assemblies: KSX* high-strength TCI reamer cutters for soft to medium-hard formations; RSX* milled-profile torque-reduction reamer rollers for torque reduction applications, and DEX* diamond-enhanced insert reamer cutters for high abrasion and impact resistance, a hard formation profile. Cutter assemblies can be changed easily on the rig floor to accommodate a range of wellbore conditions.
Applications
■ Low packed hole assemblies
■ Medium to severely packed hole assemblies
■ Extremely abrasive drilling conditions
Benefits
■ Available in all common hole sizes
■ Reduce downhole torque caused by wellbore spiraling and doglegs
■ Maintains borehole quality
■ Maintains hole gauge in extreme conditions
Features
■ Blank ended manufacturing means the tool can be configured for
near bit and string placement in the BHA
■ High-flow body increases annular total flow area (TFA) to improve
hole cleaning
■ Longer full-gauge cutting section enhances gauge maintenance
■ Proprietary seal endures high loads, temperatures, and rotary speeds
to extend bearing life
■ Three cutter assemblies allow customization for different applications
■ Cutter assemblies changed safely and easily on rig floor
■ Optional real-time data connection for use with Schlumberger
LWD tools
Service and Support
Optimum placement in the BHA is essential in any reamer application. A Schlumberger representative should always be consulted on the placement of your Borrox AP reamer. Proprietary software can be used to analyze and predict the tendencies of a particular assembly to ensure drilling objectives are achieved. The Borrox AP reamer offers multiple cutting structure options, reliability, rig site serviceability, and the capability to maintain hole gauge in extreme conditions.
Borrox AP Advanced Performance Sealed-Bearing Reamer
Lower block
Shim (upper block only when required)
Cutter assembly Cap screws
KSX cutter RSX cutter DEX cutter Borrox AP advanced performance sealed-bearing reamer
a
c
Borrox AP Advanced Performance Sealed-Bearing Reamer
Borrox AP Specifications
Hole Size†, in Body Diameter,
in (a) Bore Diameter, in Cutter Size, in Tool Length, in (b) Fishing Neck Length, in (c) Fishing Neck Diameter, in Estimated Body Weight, lbm
5.875 5.620 1.250 1.900 77.000 24.000 4.750 349 6.000 5.620 1.250 2.000 77.000 25.000 4.750 349 6.125 5.620 1.250 2.000 77.000 26.000 4.750 349 6.250 5.620 1.250 2.000 77.000 27.000 4.750 349 6.125 (large bore) 5.620 1.500 1.900 77.000 24.000 4.750 341 6.250 (large bore) 5.620 1.500 1.900 77.000 24.000 4.750 341 6.500 6.000 1.250 2.000 77.000 24.000 4.750 376 7.875 7.400 2.250 2.370 87.000 29.000 6.500 697 8.375 (6.5–in necks) 8.140 2.250 2.625 87.000 31.000 6.500 782 8.500 (6.5–in necks) 8.140 2.250 2.625 87.000 31.000 6.500 782 8.750 (6.5–in necks) 8.140 2.250 2.625 87.000 31.000 6.500 782 8.375 (7–in necks) 8.140 2.250 2.625 87.000 31.000 7.000 828 8.500 (7–in necks) 8.140 2.250 2.625 87.000 31.000 7.000 828 8.750 (7–in necks) 8.140 2.250 2.625 87.000 31.000 7.000 828 9.875 9.500 2.813 2.625 82.000 30.000 8.500 1,142 10.625 10.250 2.813 2.625 87.000 31.000 8.250 1,244 12.000 11.550 2.813 4.000 112.000 49.000 10.000 2,153 12.250 (8–in necks) 11.800 2.813 4.000 112.000 49.000 8.000 1,477 12.250 (10–in necks) 11.800 2.813 4.000 112.000 49.000 10.000 2,181 14.250 12.855 3.000 4.000 112.000 43.000 10.000 2,366 14.750 14.000 3.000 5.125 112.000 49.000 10.000 2,267 16.000 (10–in necks) 14.000 3.000 5.125 112.000 49.000 10.000 2,405 16.000 (11–in necks) 14.000 3.000 5.125 112.000 49.000 11.000 2,805 16.375 13.764 3.000 5.125 112.000 43.000 10.000 2,414 16.500 13.764 3.000 5.125 112.000 43.000 10.000 2,414 17.000 14.313 3.000 5.125 112.000 43.000 10.000 2,499 17.500 15.500 3.000 5.125 112.000 49.000 10.000 2,649 18.125 15.415 3.000 5.125 112.000 43.000 10.000 2,672 18.250 15.415 3.000 5.125 112.000 43.000 10.000 2,672 22.000‡ 20.000 3.000 5.125 116.000 38.000 10.000 3,621
† Other sizes available upon request ‡ Four-point reamer
Borrox AP with Schlumberger Real-Time LWD Data Connection Specifications Hole Size, in Body Diameter,
in Bore Diameter, in Cutter Size, in Tool Length, in Fishing Neck Length, in Fishing Neck Diameter, in Estimated Body Weight, lbm
8.500 with 5.50 FH Pins 8.000 3.400 2.000 61.000 8.500 6.875 475
12.250 with 6.62 FH Pins 11.688 4.250 2.620 58.000 8.000 8.500 781
12.250 with 7.62 H90 Pins 11.688 4.250 2.620 59.000 8.500 9.000 833
Model 60 and 62 Rotary Reamer
The Model 60 and 62 rotary reamers are true rolling reamers with optional cutting structures: The Type Q cutter delivers crushing action for reaming medium to hard formations, and the Knobby cutter is for grinding through hard formations.
The Model 60 is available in 41⁄8– to 33 7⁄8–in hole sizes. The Model 62 can be had in 61⁄2– to 83⁄4–in sizes, and offers a larger bore ID over that of the Model 60. Both models come in three- and six-point reamers for bottomhole and string placement.
Durable construction
Large-diameter, carburized, and hardened pins serve as robust abrasion-resistant bearing sections. Cutters are retained using a simple design that is easily serviced by rig personnel using common hand tools.
Applications
■ Standard runs using milled tooth rock bits, drilling surface hole
sections and shallow wells
■ High temperature conditions
■ Medium to hard and hard formations
Benefits
■ Cost effective design for many applications
■ Flexible design enables many string placement options
Features
■ Large bearing area and open circulation (Model 60) enable
high-rotary speed
■ Large diameter, carburized, hardened pins compose
abrasion-resistant bearing sections
■ Non-sealed-bearing design is cost-effective for many applications
■ “Type Q” cutters’ hard-faced, carburized steel teeth deliver
wear-resistant reaming
■ “Knobby” cutters’ tungsten carbide inserts fracture rock
a b
c
a
Three-point reamer Six-point reamer
Model 60 and 62 rotary reamer c
Model 60 and 62 Rotary Reamer
Model 60 and 62 Rotary Reamer Specifications
Hole Size,
in Cutter Size, in Bearing Pin Size, in Bearing Blocks ID Size, in and Type
Reamer Bodies Complete (String or Bottom Hole)
Maximum Body
Diameter, in (a) Body Bore, in
Three-Point Reamer Six-Point Reamer (b) (c) Weight with Cutters, lbm (b) (c) Weight with Cutters, lbm 41⁄8 13⁄8 3⁄4 3⁄4 A 33⁄4 1 50 19 100 86 32 190 45⁄8 11⁄2 7⁄8 7⁄8 A 41⁄4 1 50 19 130 86 32 250 43⁄4 11⁄2 7⁄8 7⁄8 B 41⁄4 1 50 19 130 86 32 250 55⁄8 2 1 1 A 5 1 64 25 230 105 32 450 57⁄8 2 1 1 C 5 1 64 25 230 105 32 450 6 2 1 1 A 51⁄2 11⁄4 64 25 260 105 32 510 61⁄8 2 1 1 B 51⁄2 11⁄4 64 25 260 105 32 510 61⁄4 2 1 1 C 51⁄2 11⁄4 64 25 260 105 32 510 61⁄2 2 1 1 E 51⁄2 11⁄4 64 25 260 105 32 510 75⁄8 25⁄8 13⁄8 13⁄8 A 7 15⁄8 79 33 474 121 35 960 77⁄8 25⁄8 13⁄8 13⁄8 C 7 15⁄8 79 33 474 121 35 960 83⁄8 25⁄8 13⁄8 13⁄8 A 73⁄4 17⁄8 80 34 575 122 36 1,160 81⁄2 23⁄4 13⁄8 13⁄8 A 73⁄4 17⁄8 80 34 575 122 36 1,160 85⁄8 23⁄4 13⁄8 13⁄8 B 73⁄4 17⁄8 80 34 575 122 36 1,160 83⁄4 23⁄4 13⁄8 13⁄8 C 73⁄4 17⁄8 80 34 575 122 36 1,160 91⁄2 31⁄8 13⁄4 13⁄4 A 83⁄4 21⁄4 90 39 785 135 37 1,600 95⁄8 31⁄8 13⁄4 13⁄4 B 83⁄4 21⁄4 90 39 785 135 37 1,600 97⁄8 31⁄8 13⁄4 13⁄4 D 83⁄4 21⁄4 90 39 785 135 37 1,600 105⁄8 31⁄4 13⁄4 13⁄4 A 91⁄2 21⁄4 91 39 950 137 40 1,900 11 31⁄4 13⁄4 13⁄4 D 91⁄2 21⁄4 91 39 950 137 40 1,900 12 4 21⁄4 21⁄4 C 101⁄2 213⁄16 112 501⁄2 1,088 155 451⁄2 2,230 121⁄4 4 21⁄4 21⁄4 E 101⁄2 213⁄16 112 501⁄2 1,088 155 451⁄2 2,230 133⁄4 4 21⁄4 21⁄4 E 113⁄4 213⁄16 112 501⁄2 1,445 155 431⁄2 2,600 143⁄4 51⁄2 21⁄2 21⁄2 A 123⁄4 213⁄16 112 49 1,705 155 431⁄2 2,600 15 51⁄2 21⁄2 21⁄2 C 123⁄4 213⁄16 112 49 1,705 155 431⁄2 2,600 171⁄2 51⁄2 21⁄2 21⁄2 E 15 3 112 47 2,400 164 45 5,100 181⁄2 51⁄2 21⁄2 21⁄2 A 163⁄8 3 112 47 2,650 164 45 5,100 20 51⁄2 21⁄2 21⁄2 M 163⁄8 3 112 47 2,650 164 45 5,100 24 7 3 3 A 22 3 122 50 3,900 164 45 5,100 26 7 3 3 C 22 3 122 50 3,900 164 45 5,100 337⁄8† 7 3 3 C 30 3 130 42 8,900 164 45 5,100
† Model 60 33 7⁄8–in tool available in four-cutter configuration only.
Ordering instructions, please specify: • Three-point or six-point • Bottomhole or string reamer • Hole size
• Drill collar OD
• Type of cutters to be installed in the reamer • Size, type and location of the connection • Cast- or pressed-steel thread protectors
The Shock Sub* impact and vibration reduction sub is a drillstring component that absorbs and dampens the variable-axial dynamic loads produced by the drill bit during “normal” drilling operations. Left unchecked, a roller cone bit produces a pattern of “peaks and valleys” on the bottom of the borehole as it rotates. With each revolution of the bit, the cones will tend to follow this sinusoidal contour producing a cyclical oscillation of the drillstring.
The Shock Sub interrupts this harmonic cycle by using a bidirectional-spring action enabling it to automatically adjust to a wide range of values for weight on bit (WOB). As axial loads are produced, energy is absorbed through the use of its Belleville spring assembly while force dampening is accomplished by mechanical friction.
Applications
■ Drilling competent sediments in straight holes with roller cone or
hammer bits
■ Directional drilling: hard formations, horizontal sections, directionally
drilled crossings
■ Milling operations: sections, windows, casing
■ Underreaming and hole opening
■ Coiled tubing drilling operations
Shock Sub
Shock Sub Specifications Overall Diameter, in
[mm] Internal Diameter, in [mm] Tool Joint Connection, in Tensile Yield, lbf [N] Torsional Yield, lbf.ft [N.m] Approximate Weight, lbm [kg] Length, ft [m] 4.75 [121] 1.75 [44] 3 1⁄2 IF 415,000 [1,846,000] 17,500 [23,700] 600 [270] 11.5 [3.50] 5.0 [127] 1.75 [44] XT39 589,000 [2,620,000] 31,000 [42,000] 800 [360] 11.5 [3.50] 6.5 [165] 2.25 [57] 4 1⁄2 IF 41⁄2 XH 800,000 [3,559,000] 57,000 [77,200] 1,300 [590] 12.0 [3.68] 8.0 [203] 3.00 [76] 6 5⁄8 Reg 1,100,000 [4,893,000] 84,000 [113,900] 1,800 [817] 13.5 [4.12] 9.5 [241] 3.00 [76] 7 5⁄8 Reg 1,800,000 [8,006,000] 150,000 [203,300] 2,700 [1,225] 13.5 [4.12] 12.0 [305] 3.25 [83] 7 5⁄8 H90 2,300,000 [10,230,000] 250,000 [339,000] 4,500 [2,041] 13.8 [4.21] 14.0 [356] 3.25 [83] 8 5⁄8 H90 2,300,000 [10,230,000] 400,000 [542,300] 6,200 [2,812] 14.3 [4.36] Benefits ■ Increased ROP
■ Longer life for the cutting structure and bearings because of reduced
impact loads
■ Extended connection life
■ Reduced shock loads on surface equipment
■ Lower drilling cost per foot
Features
■ High-quality, hardened-steel tool body for durability
■ Rotary shoulder connections incorporate API stress-relief groove
and bore-back box
■ Seals endure temperatures up to 450 degF
■ Compression/extension spring action counters axial loads, maintains
near constant WOB
■ Belleville spring stack engineered for optimal WOB
■ Spring rate adjustable to meet application-specific requirements
■ Seals isolate internal components from drilling fluid
The diamond-enhanced insert (DEI) reamer delivers effective hole reaming across a broad range of applications. Its advanced integral body design incorporates tough, state-of-the-art synthetic DEIs that shear the hole wall, providing a quality, full-gauge wellbore in soft to medium-hard formations.
Flexible design
Each insert is securely brazed into the tool body, so there are no moving parts to wear or fail. Consequently, the tool is not affected by hot hole conditions. It can be placed at any point in the BHA. The tapered body profile enables reaming both downward and upward.
Improved circulation rates
The dual spiral and tapered design facilitates high circulation rates and the efficient transport of cuttings past the tool. The larger circulation area can be an advantage when annular restriction is a concern.
Applications
■ Removing ledges and opens under-gauge portions of build sections
for directional work
■ Removing keyseats
■ High-temperature reaming
Benefits
■ Produces high-quality full-gauge wellbores
■ Allows greater circulation
Features
■ No moving or sealed components guards against downhole failures
due to heat or other severe downhole conditions
■ Assembling flexibility enables placement in BHA at any point
■ Synthetic, diamond-enhanced inserts compose durable cutting
structure capable of maintaining full-gauge hole in soft to medium-hard formations
■ Spiral body facilitates high-circulation rates and efficient evacuation
of cuttings
■ Tapered body profile enables reaming downward and upward
Diamond-Enhanced Insert Reamer
Rib length
Diamond-Enhanced Insert Reamer Specifications
Hole Size, in Rib Length, in Bore Diameter, in Neck Diameter, in Tool Length, in Approximate Weight, lbm
6 18 2 43⁄4 60 265 77⁄8 22 21⁄4 61⁄4 64 530 81⁄2 22 21⁄4 63⁄4 64 635 83⁄4 22 21⁄4 63⁄4 64 655 97⁄8 22 213⁄16 7 66 755 Tool length
Inline Reamer
The inline reamer’s four blades and robust cutter elements clean and clear horizontal wellbores for shale applications, eliminating costly wiper trips. Its innovative carbide-button gauge design reduces rotating torque and drag on the drillstring. In highly abrasive formations, the gauge pad can be designed with PDC buttons for enhanced abrasion resistance.
The inline reamer stabilizer is typically run in pairs within the drillstring and positioned above the MWD drill collar. Configured from top down it includes a stabilizer, a joint of Hevi-Wate* transition drillpipe, and a second stabilizer.
Applications
■ Cleaning cuttings from shale-dominated wellbores
■ Clearing cutting beds from horizontal shale wells
■ Eliminating ledges in horizontal shale wells
Benefits
■ Eliminates the costs associated with dedicated wiper trips
Features
■ Open or wrap tool design available for flow-by flexibility
■ Four blades for reaming efficiency
■ PDC buttons on taper effectively cleans borehole
■ Standard carbide buttons on gauge pad reduce rotating torque and
drag; mixed cutter type (PDC or carbide) available on gauge pad
Inline reamer Inline Reamer Specifications
OD, in [mm] 4.75 [120.7]
Minimum ID, in [mm] 2.6875 [68.3]
Gauge OD, in [mm] 5.875 [149.2]
Fishing neck OD, in [mm] 4.75 [120.7]
Fishing neck length, in [mm] 18–24 [457.2–609.6]
Cutter type PDC on taper
Gauge pad buttons Carbide or PDC
Overall length, in [mm] 60–66 [1524–1676.4]
Number of blades 4
Up connections 3½ IF
The gauge indicator sub generates an increase in torque when the drill bit wears below nominal gauge specification. This cost-effective capability enables the driller to detect drillbit gauge wear by a torque increase as the indicator sub’s wear-resistant blades make contact with the hole wall, reducing reaming time and maximizing ROP. A short, efficient body design enables the sub to be made up between the drill bit and drilling mud motor or rotary steerable system. The gauge indicator sub is available in a broad range of sizes.
Applications
■ Directional or straight hole, motor or rotary, steerable applications
where monitoring drillbit wear is necessary to prevent under-gauge holes
Benefits
■ Reduces reaming time
■ Extends bit life
Features
■ Configuration extends bit life by centering bit in wellbore
■ Cutting design delivers a smoother, high-quality wellbore
■ Short design facilitates placement at the bit, regardless of
directional system
■ Type 300 hardfacing ensures long life in abrasive environments
Gauge Indicator Sub
Unless otherwise requested, nominal gauge diameter for this product is OD +0 in, -1⁄32 in
The DOG* drilling on gauge sub has been specifically designed to deliver at-the-bit reaming. Its short body design and durable cutting structure enables placement between the bit and motor for directional applications. This results in a smoother build section and reduction in hole drag allowing for better weight transfer to the drill bit. The cutting structure is comprised of synthetic diamond-enhanced inserts, which gives the DOG sub its continuous reaming capability. Each insert is brazed into the body, eliminating moving parts found in conventional reamers.
Applications
■ Directional projects where maintaining hole gauge is problematic
■ Directional wells where doglegs demand reaming runs through
build sections
■ Near-bit reaming in packed-hole assemblies, sub is first point of
stabilization for BHA
DOG Drilling On Gauge Sub
Shoulder to shoulder
length
DOG drilling on gauge sub DOG Drilling On Gauge Sub Specifications
Hole Size, in Connection Size
and Type Bore Diameter, in Shoulder to Shoulder Length, in Rib Length, in Weight, lbm
43⁄4 27⁄8 Reg 11⁄4 61⁄2 57⁄8 39 57⁄8 31⁄2 Reg 11⁄4 73⁄8 67⁄16 51 6 31⁄2 Reg 11⁄4 73⁄8 63⁄8 54 61⁄8 31⁄2 Reg 11⁄4 71⁄2 67⁄16 57 61⁄4 31⁄2 Reg 11⁄4 71⁄2 67⁄16 61 61⁄2 31⁄2 Reg 11⁄4 77⁄8 65⁄8 66 63⁄4 31⁄2 Reg 11⁄4 81⁄8 65⁄8 71 73⁄8 41⁄2 Reg 21⁄4 81⁄4 65⁄8 64 71⁄2 41⁄2 Reg 21⁄4 73⁄8 63⁄8 79 77⁄8 41⁄2 Reg 21⁄4 8 65⁄8 88 81⁄4 41⁄2 Reg 21⁄4 83⁄8 67⁄8 95 83⁄8 41⁄2 Reg 21⁄4 83⁄8 71⁄8 102 87⁄16 41⁄2 Reg 21⁄4 83⁄8 7 107 81⁄2 41⁄2 Reg 21⁄4 83⁄8 7 111 83⁄4 41⁄2 Reg 21⁄4 89⁄13 71⁄4 115 9 41⁄2 Reg 21⁄4 91⁄2 67⁄8 110 91⁄2 65⁄8 Reg 3 85⁄8 77⁄8 112 97⁄8 65⁄8 Reg 3 91⁄8 73⁄4 159 105⁄8 65⁄8 Reg 3 97⁄8 81⁄8 181 11 65⁄8 Reg 3 103⁄8 83⁄8 187 115⁄8 65⁄8 Reg 3 101⁄2 87⁄8 174 121⁄8 65⁄8 Reg 3 111⁄2 7 214 121⁄4 65⁄8 Reg 3 113⁄8 9 206 143⁄4 75⁄8 Reg 33⁄8 217⁄8 93⁄4 563 151⁄2 75⁄8 Reg 33⁄8 221⁄4 71⁄4 523 16 75⁄8 Reg 33⁄8 225⁄8 101⁄8 578 171⁄2 75⁄8 Reg 3 241⁄8 105⁄8 706 20 75⁄8 Reg 3 263⁄4 83⁄5 980 22 75⁄8 Reg 3 287⁄8 9 1,122 Benefits
■ Can be placed between bit and mud motor for directional
applications
■ Provides reaming and contact behind bit, wiping out ledges as
drilling progresses
■ Stabilizes BHA assembly
■ Increases drilling performance
Features
■ Maintains hole size when drill bit loses gauge, reduces, or eliminates
need to ream back to bottom with directional assembly
■ Synthetic diamond-enhanced inserts comprise durable cutting
structure, maintain full-gauge hole in soft to medium-hard formations
■ No moving parts to wear or fail ensures reliability
■ Short body facilitates reaming directly at bit
Rib length
The diamond-enhanced insert (DEI) stabilizer is purpose-built to stabilize the BHA in hard or abrasive formations. Synthetic DEI technology combines with proven Type 300 hardfacing for maximum stability and abrasion resistance. The strategically placed inserts ream ahead of the stabilizer blades, maintaining a full gauge and extending service life. The DEI stabilizer is made for packed hole, directional, and pendulum bottomhole assemblies.
Applications
■ BHA stabilization for hard or abrasive formations
■ Increases drilling performance of packed hole, directional and
pendulum bottomhole assemblies
Benefits
■ Dependable reaming in hard or abrasive formations
■ Maintains full-gauge borehole
Features
■ DEI inserts maintain hole gauge, extend stabilizer life and improve
BHA performance
■ Insert profile reduces drillstring torque and drag
Diamond-Enhanced Insert Stabilizer
DEI stabilizer
Blade length
Diamond-Enhanced Insert Stabilizer Specifications Hole Size, in Overall Length,
in Neck Overall Diameter, in Top Neck Length, in Bottom Neck Length, in Blade Length, in (a) Blade Length, in (b)
83⁄8 75 61⁄2 30 24 16 6 81⁄2 75 61⁄2 30 24 16 6 105⁄8 77 8 30 24 16 6 121⁄4 81 8 30 24 16 6 121⁄4 81 91⁄2 30 24 16 6 a b Tool length
Other types of hard metal wear surfaces available upon request. Nominal rib diameter +0 in, -1⁄ 32 in.
Ordering instructions, please specify: • Hole size
• Drill collar OD • Size and type of connection • Cast- or pressed-steel thread protectors The double-diamond combo tool is
manufactured from high-strength alloy steel as a one-piece tool. It is an extremely effective bottomhole stabilizer where severe crooked hole tendencies are encountered.
High-quality borehole
The unitized construction features two sets of three-blade spiraled ribs designed to reduce damage to the hole wall and ensure maximum fluid circulation. Optimally spaced diamond-enhanced inserts (DEIs) provide the reaming action necessary to keep the hole in gauge.
Rugged construction
The inserts are brazed into the tool body, ensuring dependable service and complete repairability. Type 300 hardfacing provides optimum wear resistance and stabilizer blade life.
Improved ROP
The increased hole wall contact area allows more drilling weight to be applied, thus improving penetration rates while staying within acceptable deviation limits.
Applications
■ Drilling crooked holes that call for
packed-hole assemblies
■ Maintaining the tangent section of a well
during directional drilling
Double-Diamond Combo Tool
Blade length
Double-diamond combo tool
DEI placement
Double-Diamond Combo Tool Specifications
Hole Size, in Blade Length, in Bore Diameter, in Neck Diameter, in Tool Length, in Approximate Weight, lbm
77⁄8 12 21⁄4 61⁄4 65 900 81⁄2 12 21⁄4 63⁄4 65 980 83⁄4 12 213⁄16 63⁄4 65 990 121⁄4 18 3 91⁄2 76 2,000 Tool length Benefits
■ Serves as first point of hole wall
contact directly at bit, greatly improves BHA efficiency
■ Stabilizes BHA in holes with severe
crooked-hole tendencies
■ Reduces hole-wall damage, ensures
maximum circulation
■ Endures high drilling weight
Features
■ Manufactured from high-strength alloy steel
as a one-piece tool for reliability
■ Diamond-enhanced inserts deliver reaming
action to keep hole in gauge
■ Optimized insert spacing for enhanced
performance
■ Inserts brazed into tool body ensures
durability
■ Type 300 hardfacing provides optimum wear
resistance and stabilizer blade life
■ Tong area between stabilizers enables
bottom stabilizer blades to cover box connection
The Integral Blade Stabilizer dampens lateral vibrations acting on the BHA. It also stiffens the BHA in a packed assembly to build an angle, drop an angle, or both in a pendulum assembly. It is a single-piece tool made from high-strength alloy steel.
Maintain hole quality
The unitized construction features three spiraled ribs, designed to minimize downhole torque, reduce damage to the hole wall, and ensure maximum fluid circulation.
Wide range of applications
The IBS is well-suited for use in most formations, from soft and sticky to hard and abrasive. Type 200 and Type 300 wear surfaces are available. The tool can be supplied in both “open” and “full-wrap” designs for optimum hole wall contact. In addition, it is available in both bottomhole and string designs, providing the flexibility to run it anywhere in the BHA.
One-piece construction
The integral blades and tool body eliminate the risk of leaving components or pieces in the hole.
Integral Blade Stabilizer
Integral Blade Stabilizer Specifications
Hole Size Range, in Drill Collar Overall Diameter Range, in Bore, in Overall Length, in (a) Blade Length, in (b)
43⁄4 33⁄4 11⁄2 62 10 57⁄8 43⁄4 13⁄4 62 10 63⁄4 51⁄2 21⁄4 64 12 77⁄8 61⁄2 213⁄16 64 12 81⁄2–83⁄4 63⁄4–7 213⁄16 65 13 91⁄4–97⁄8 71⁄4–81⁄4 213⁄16 66 13 105⁄8 81⁄4 213⁄16 66 13 12–121⁄4 81⁄4–91⁄2 3 72 15 171⁄2 10 3 76 15 24 10 3 91 20 28 10 3 95 20
Nominal rib diameter as follows: • 4¾–12¼ in + 0, -1⁄32 in
• 13¾–17 ½ in + 0, -1⁄16 in
• 18–28 in +0, -1⁄8 in
Non-standard tolerances are available upon request.
Applications
■ Packed-hole assemblies that require the
placement of multiple stabilizers throughout the three zones of stabilization
■ Pendulum assemblies
■ Applications requiring the placement of
stabilizers in the BHA and upper drill-collar string to reduce vibration in drill collars
Benefits
■ Works in most formations
■ Available in bottomhole and string design,
runs anywhere in BHA
■ Prevents wall damage while ensuring
maximum circulation
Features
■ Integral blades and tool body, eliminating
the risk of leaving components or pieces in the hole
■ Available in both open- and full-wrap
designs, providing optimum hole wall contact while ensuring maximum fluid bypass area
■ Available in Type 200 and Type 300
wear surfaces Integral Blade Stabilizer with Type 300 wear surface
a b
The Ezy-Change* type II stabilizer is designed around a rugged, one-piece mandrel constructed of high-strength alloy steel, with ample tong space for handling ease and extra length for recutting connections. The rig-replaceable, integral blade sleeves are available in two different hardfacing options or with tungsten carbide inserts (TCIs).
Versatile and space-saving
The Ezy-Change stabilizer is a popular choice for remote areas or where storage problems exist. One mandrel series can be used for several different hole sizes, reducing the need for a large mandrel inventory on location. The sleeves are easily changed on the rig floor, either when changing hole size or when the sleeves have worn under gauge. This versatility also allows a convenient way to change the type of stabilizer wear surface to match drilling conditions.
Applications
■ Mild to medium packed hole assemblies
■ Pendulum assemblies
■ Directional drilling assemblies
■ Harmonic vibration control
Benefits
■ Reduces the need to maintain large mandrel inventory on location
■ Small footprint enables placement in remote or space-
constrained locations
Features
■ Sleeves 171⁄2 in and smaller feature three spiral blades, four straight
blades for larger sizes
■ Large flow-by area for maximum flow
■ Multiple hardfacing options
■ Robust one-piece mandrel design
■ Ample length for multiple re-cuts
Ezy-Change Type II Rig-Replaceable Sleeve-Type Stabilizer
Sleeve dressed with Type 300 hardfacing Bottom neck diameter Fishing neck length Drill collar diameter Upset diameter
Sleeve dressed with Type 200 tungsten carbide inserts
Sleeve dressed with Type W hardfacing
Nominal overall length
Notes:
• Non-standard length mandrels and tolerances available upon request • Bottomhole tools are provided with bit box connection
• Thread roots are cold worked (except bit box) and phosphate coated • Standard bore is 213⁄16 in, other diameters are available upon request
• Sleeves can be ordered in all standard hole sizes between 81⁄2 in and 28 in
• Nominal rib diameter as follows: • 81⁄2–12 1⁄4 in + 0, -1⁄32 in
• 14 3⁄4–171⁄2 in + 0, -1⁄16 in
• 22–28 in + 0, -1⁄8 in
Ordering instructions, please specify: • Series number
• Drill collar or fishing neck diameter • Bore (if other than standard)
Sleeve Specifications
Hole Size, in Tool Series Drill Collar Size
Range, in Length, in Body Diameter, in Blade Length, in Weight, lbm Recommended Makeup Torque, lbm.ft
81⁄2 62 6 1⁄4–63⁄4 14 71⁄2 12 70 4,500–5,500 65 61⁄2–71⁄4 14 71⁄2 12 80 3,500–4,500 83⁄4 62 6 1⁄4–63⁄4 14 71⁄2 12 75 4,500–5,500 65 61⁄2–71⁄4 14 71⁄2 12 85 3,500–4,500 97⁄8 62 6 1⁄4–63⁄4 14 73⁄4 11 85 4,500–5,500 65 61⁄2–71⁄4 14 73⁄4 11 95 3,500–4,500 121⁄4 77 73⁄4–81⁄4 14 91⁄4 11 140 7,000–8,000 85 81⁄2–9 14 10 11 130 9,000–10,000 96 9–10 14 11 11 110 10,000–12,000 143⁄4 77 73⁄4–81⁄4 18 11 14 330 7,000–8,000 85 81⁄2–9 18 11 14 300 9,000–10,000 96 9–10 18 11 14 270 10,000–12,000 171⁄2 77 73⁄4–81⁄4 18 11 12 370 7,000–8,000 85 81⁄2–9 18 11 12 340 9,000–10,000 96 9–10 18 11 12 310 10,000–12,000 22 96 9–10 22 12 12 1,780 10,000–12,000 24 96 9–10 32 12 16 2,050 10,000–12,000 26 96 9–10 32 12 16 2,110 10,000–12,000 28 96 9–10 32 12 16 2,190 10,000–12,000
Ezy-Change Type II Rig-Replaceable Sleeve-Type Stabilizer
Mandrel Specifications Tool
Series Sleeve Hole Size Range, in Drill Collar (Fishing Neck) Diameter, in
Upset Diameter,
in Bottom Neck Diameter, in Overall Length, in Fishing Neck Length Weight, lbm String (Box Up), in Bottom Hole (Pin Up), in
62 81⁄2–97⁄8 61⁄4–63⁄4 71⁄2 61⁄4 65 27 22 475 65 81/2–97⁄8 61⁄2–71⁄4 73⁄4 61⁄2 65 27 22 575 77 121⁄4–171⁄2 73⁄4–81⁄4 91⁄4 73⁄4 66 27 22 800 85 121⁄4–171⁄2 81⁄2–9 97⁄8 81⁄2 66 27 22 1,000 96 143⁄4–20 91⁄2–10 11 95⁄8 66 27 22 1,200 96 22–28 91⁄2–10 11 95⁄8 90 27 22 1,780
Neyrfor Traditional
Neyrfor Traditional* standard turbodrill’s innovative design incorporates stabilizers and straight- or bent-bearing sections for directional-steerable applications, vertical performance, and rotary drilling. The turbodrill’s design allows the driveshaft to rotate at a higher rpm while remaining dynamically stable, which produces
unsurpassed ROP without the negative effects of excess torque.
Power and Bearing Section
The Neyrfor Traditional turbodrill is based on a concentric design with a fluid connect rotor and stator-power drive system. These two components are offered in different configurations to produce a range of power characteristics enabling turbodrills to be designed for specific applications, and an all metallic option is available for HPHT conditions. Extended- and high-flow power sections are available in standard tool sizes and configurations. Additionally, a diamond-bearing pack design reduces vibration and noise, which can interfere with downhole measurement tools.
With an unmatched capability to convert hydraulic energy from the mud column to mechanical energy at the bit, the Neyrfor Traditional turbodrill drive system delivers greater mechanical drilling power than any other system under equal hydraulic conditions.
The Neyrfor Traditional turbodrill had set the benchmark for downhole drive system reliability: run times of up to 800 hours have minimized NPT caused by downhole tool failures and problems related to HPHT applications. Applications ■ Directional drilling ■ High-pressure, high-temperature (HPHT) drilling ■ Straight-hole drilling ■ Geothermal drilling ■ Underbalanced drilling
■ Single- or two-phase fluids
Benefits
■ High-power performance
■ Mitigates vibration
■ High-temp capabilities, 260 degC
■ Produces excellent borehole quality
■ Consistent and predictable tool face control
■ Unsurpassed reliability and operating life
■ Reduces NPT
Features
■ Rig-adjustable or fixed-bent housing section
■ Rig interchangeable stabilizers
■ Concentric-balanced design
■ Fluid-connect drive system
Components
■ Power section
■ Rig-interchangeable stabilizers
■ Pin down straight- or
steerable-bearing section
Available Tool Sizes ■ 27⁄8 in ■ 33⁄8 in ■ 43⁄4 in ■ 65⁄8 in ■ 71⁄4 in ■ 91⁄2 in
Interchangeable mid-body stabilizer
Adjustable bent housing
Rotor and stator blades Interchangeable lower-body stabilizer
PDC thrust bearings
Neyrfor Delta* high-performance directional turbodrill is specifically designed to meet demanding directional and precision horizontal drilling applications. This high-performance turbodrill has the shortest bit to bend in its class, which enables shorter radius-curve drilling. This capability decreases the course corrections that are common to horizontal and tangent section drilling while increasing ROP. The Neyrfor Delta turbodrill’s stabilizers enhance weight transfer to the bit enabling the turbodrill to maximize borehole cleaning and minimize wellbore rugosity. Both conditions promote wellbore evaluation, casing running, cementing, and minimize problems associated with drilling ahead.
Neyrfor Delta turbodrill BHAs run with a proprietary stabilizer placement and optimization software package, which maximize performance and directional predictability while minimizing NPT caused by downhole tool failures and problems related to HPHT applications. Consistent predictable tool face control and increased dogleg capabilities make the Neyrfor Delta high-performance directional turbodrill ideal for directional applications and sidetracking cement plugs and whipstocks.
The Neyrfor standard turbodrill is based on a concentric design with a fluid connect rotor and stator-power drive system. These two components are offered in different configurations to produce a range of power characteristics enabling turbodrills to be
Neyrfor Delta
designed for specific applications. An all metallic option is available for HPHT conditions. Extended- and high-flow power sections are available in standard tool sizes and configurations. Additionally, a diamond-bearing pack design reduces vibration and noise, which can interfere with downhole measurement tools.
Applications
■ Directionally drills curved, horizontal, and
tangent applications
■ High-pressure, high-temperature (HPHT)
directional drilling
■ Cement and whipstock sidetracks
■ PDC and diamond- impregnated
bit applications
Benefits
■ Unsurpassed reliability and operating life
■ Reduces slide time 50%
■ Increases dogleg capabilities 60%
■ Reduces NPT
■ High-temperature capabilities, 260 degC
■ Produces excellent borehole quality
■ Consistent and predictable tool face control
Features
■ Shortest bit to bend in class
■ Proprietary engineered stabilizer placement
and profile software
■ Concentric-balanced design
■ Fluid-connect drive system
Components
■ Power section
■ Engineered Neyrfor Delta Series
directional stabilizers
■ Pin down steerable-bearing section
■ Power and Bearing Section
Available Tool Sizes ■ 43⁄4 in
■ 65⁄8 in
■ 91⁄2 in
The Neyrfor LC3* turbodrill locking clutch system was specifically designed for drilling and reaming environments that induce bit sticking. When added to a Neyrfor Traditional* standard turbodrill or Neyrfor Delta* high-performance directional turbodrill configuration, it can help free a stuck bit. The clutch engages when the turbodrill drive shaft stops or the rpm is below that of the rotary string speed. Because the drillstring, turbodrill housing, and output drive shaft are linked together by the locking clutch, operators can apply torque from the top drive or rotary table directly to the bit by engaging the LC3 locking clutch system. Once the bit is freed, the clutch disengages and normal drilling operations can be resumed. Bit type and directional well applications are evaluated on a per-well basis.
LC3 performance improvements
■ Material changes—1,400% more resistant
to stress damage
■ Design modification—28% more drilling
durability
■ Optimized placement to be run with Neyrfor
or Delta turbodrills
Applications
■ Fractured or faulted formations
■ Drilling in applications that induce
bit sticking
Benefits
■ Reduces need for fishing and sidetracking
operations
■ Improves directional drilling reliability
■ Increases drilling time
■ Lowers NPT
Features
■ Drive shaft locks to housing, so torque can
be applied directly to bit from the surface
■ Instant engagement allows bit to keep
drilling, reducing risk of becoming stuck if turbine stalls
Neyrfor LC3 Turbodrill Locking Clutch
In this cutaway view of the locking clutch system, the pawl is disengaged: its position during drilling.
Locking clutch pawl
AP Impact System
The complex and expensive drilling assemblies used in today’s technologically advanced drilling operations represent a greater investment than ever before. As a result, lost-in-hole (LIH) incidents can cost operators hundreds of thousands of dollars related to lost equipment, its recovery, plugging back, and drilling around a LIH drillstring. The Schlumberger AP Impact* advanced performance downhole impact system can help protect operators from these costly setbacks by greatly reducing the risk of losing downhole drilling equipment, such as rotary steerable, MWD, and LWD systems.
The AP Impact system includes:
■ Hydra-Jar AP Tool
■ Accelerator AP Tool
■ Jar-Pact Analysis Program
■ Data Acquisition Program
Applications
■ For differential sticking, hole sloughing, or other potential
stuck-in-hole problems
■ Casing swaging operations requiring impact for successful completion
■ Fishing operations requiring significant down-hitting impact or
alternating up-and-down jarring force
■ When using downhole tools such as directional, and
MWD/LWD equipment
Hydra-Jar AP
Recognized as the industry’s premier impact tool, the Hydra-Jar AP* double-acting hydraulic drilling jar offers drillers matchless operational flexibility. The driller controls the direction, intensity, and frequency of the downhole impacts. And, since the system works without applied torque, the orientation of directional-drilling tools is maintained throughout the jarring operation. The tool also offers the driller an important option: to jar up, or down, with a force ranging from a light blow to an extra-heavy impact.
Accelerator AP tool
The Accelerator AP* impact tool augments the Hydra-Jar AP’s capability by providing additional stretch in the drillstring. In this way, it answers challenges such as hole drag, or if the drillstring is not heavy or long enough. By increasing the velocity of the mass applied to the jar, the Accelerator AP ensures optimum impact force from the Hydra-Jar AP.
Jar-Pact Analysis Program
The Jar-Pact* impact tool BHA placement software analysis program includes proprietary software that enables Schlumberger engineers to model the placement and performance of the AP Impact system. This ensures that the Hydra-Jar AP and Accelerator AP will deliver superior, real-world performance for the customer’s specific application. Using information from the operator’s well plan, including wellbore and BHA parameters, the Jar-Pact analysis program determines the optimum placement for impact tools.
Data Acquisition Program
The data acquisition program is a service check to ensure that every Hydra-Jar AP is tested by Schlumberger prior to being sent to the rig. The testing process uses pressure transducers to measure tool function and verify that it is performing to specification.
Note:
Jar-Pact Program should be utilized to optimize performance of Accelerator AP and Hydra-Jar AP Tools. Contact Schlumberger for more information.
Ordering instructions, please specify: • Hole size
• Drillstring component OD where jar will be used • Connection size and type
Jar-Pact Program and Data Acquisition Program
Jar-Pact Program
The Jar-Pact impact tool BHA placement software allows our engineers to model the placement and performance of the AP Impact system to ensure that the Hydra-Jar AP double-acting hydraulic drilling jar and the Accelerator AP impact tool will deliver superior performance in your specific application.
Optimum placement of jar in the BHA
Using information from the operator’s well plan—including borehole and BHA parameters—the software recommends the optimum placement for the tools. This is a critical requirement in order to avoid locating the tools in or near the drillstring neutral point or transition zones. The Jar-Pact software also ensures that the ratio of the hole size to the size of the tools is within recommended guidelines.
Data Acquisition Program
The Data Acquisition Program ensures that all AP Impact tools are tested to specification before being sent to a wellsite. The system uses two pressure transducers to perform both a push and a pull test for both short and full detent. A laser rangefinder device is used to measure stroke length. The results, which include the test readings, tool serial number, date and time, are entered in a reference database and can be viewed as raw data or in a graphical format.
Benefits
■ Records push/pull, time, and stroke length test data
■ Displays real-time graph and timer
■ Generates electronic tool test report
■ Archives test data
■ Provides verification data for critical jar parameters
■ Archives or transfers data easily
■ Eliminates human error
■ Provides data clarity
Jar-Pact program
The Hydra-Jar AP double-acting hydraulic drilling jar is used to amplify the force applied at surface in order to free stuck drillstem components during drilling or workover operations. The direction of jarring can be both up and down. The jar uses a unique temperature-compensation process to provide consistent impact, blow after blow, and high-temperature seals that make it the best choice for hostile drilling conditions.
In most applications the tool should be run in conjunction with the Accelerator AP tool to increase the impact while protecting the drillstring and surface equipment from shock.
Consistent performance controlled by driller
The Hydra-Jar AP tool gives the driller the operational flexibility of controlling the direction (up or down), force, and frequency of impact. The tool is balanced to hydrostatic pressure through ports open to the wellbore, ensuring consistent hitting performance regardless of changes in downhole pressure. It is also temperature-compensated through the use of a unique detent system. This provides more consistent loading and firing of the jar over a broad range of borehole temperatures. These features—combined with careful materials selection and field-proven engineering—deliver a uniquely rugged, reliable downhole impact system.
Suitability for all drilling environments
The Hydra-Jar AP drilling jar performs effectively in every drilling environment—land or offshore, vertical or deviated wells, and ultradeep or ultrahot boreholes. Because the system works without applied torque, directional drilling tools maintain their orientation throughout the jarring operation. The jar may be run in compression or tension, enabling optimized placement in the string.
Flexibility and efficiency
The fullbore design minimizes pressure losses and provides wireline tool compatibility. The jar makes up, racks, and handles like a standard-length drillpipe, reducing trip time. It provides up, down, or up-and-down impact without torquing or tripping for adjustments. The Hydra-Jar AP double-acting hydraulic
Hydra-Jar AP
Applications
■ Drilling or workover operations
■ HPHT drilling conditions
Benefits
■ Operates in all drilling environments: land
or offshore, vertical or deviated wells, ultradeep or ultrahot wellbores
■ Expands options for drilling, coring,
cementing, testing, fishing, workover and remedial operations
Features
■ Jarring direction, duration, and impact
intensity are controlled from rig floor
■ Fullbore design minimizes pressure losses
and provides wireline tool compatibility
■ Allows optimum placement in compression
or tension for best impact/impulse
■ Safety clamp enables jar to be made up,
racked, and handled like drillpipe joint, reducing trip time
■ Optional safety lock prevents jar from
firing accidentally
■ Jar provides up and down impact without
torque or tripping for adjustments
■ Tool length enables tool makeup and rack
like standard length drillpipe
■ Temperature rated to 500 degF, optional
ultra high temperature seals rated to 650 degF
■ Seals are rated to 20,000 psi
■ Circulation rated to 10,000 psi
Hydra-Jar AP
Hydra-Jar AP
Hydra-Jar AP Specifications Outer Diameter, in [mm] Inner Diameter, in [mm] Tool JointConnection Overall Length Extended, ft.in [mm] Maximum Detent Working Load, lbf [N] Tensile Yield Strength, lbf [N] Torsional Yield Strength, lbf.ft [N.m] Up Stroke, in [mm] Down Stroke, in [mm] Total Stroke, in [mm] Tool Weight, lbm [kg] 33⁄8 [85.73] 11⁄2 [38.10] 23⁄8 API IF 24.42 [7,442] 44,000 [195,712] 236,062 [1,050,004] 6,842 [9,276] 7 [178] 7 [178] 21 [533] 500 [227] 41⁄4 [107.95] 2 [50.80] 27⁄8 API IF 29.83 [9,093] 70,000 [311,360] 377,871 [1,680,770] 15,381 [20,853] 8 [203] 7 [178] 25 [635] 800 [362] 43⁄4 [120.65] 21⁄4 [57.15] 31⁄2 API IF 29.83 [9,093] 95,000 [422,560] 492,284 [2,189,679] 19,126 [25,930] 8 [203] 7 [178] 25 [635] 1,050 [476] 51⁄8 [130.18] 21⁄4 [57.15] WT 38 29.83 [9,093] 95,000 [422,560] 492,284 [2,189,679] 30,000 [40,650] 8 [203] 613⁄16 [173.08] 25 [635] 1,155 [524] 61⁄4 [158.75] 23⁄4 [69.85] 41⁄2 XH 31.17 [9,499] 150,000 [667,200] 730,324 [3,248,481] 40,505 [54,915] 8 [203] 7 [178] 25 [635] 1,600 [725] 61⁄4 Mod [158.75] 23⁄4 [69.85] 41⁄2 XH 31.17 [9,499] 150,000 [667,200] 964,207 [4,288,792] 50,757 [68,814] 8 [203] 7 [178] 25 [635] 1,600 [725] 61⁄2 [165.10] 23⁄4 [69.85] 41⁄2 Reg IF 31.17 [9,499] 175,000 [778,400] 964,207 [4,288,792] 54,796 [74,290] 8 [203] 7 [178] 25 [635] 1,850 [839] 7 [177.80] 23⁄4 [69.85] 5 H 90 31.50 [3,601] 230,000 [1,023,040] 1,179,933 [5,248,342] 67,396 [91,372] 8 [203] 8 [203] 25 [635] 2,600 [1,179] 71⁄4 [184.15] 23⁄4 [69.85] 51⁄2 H 90 31.50 [3,601] 240,000 [1,067,520] 1,261,162 [5,337,600] 84,155 [114,093] 8 [203] 8 [203] 25 [635] 3,000 [1,360] 73⁄4 [196.85] 3 [76.20] 65⁄8 Reg 32.00 [9,754] 260,000 [1,156,480] 1,315,225 [5,850,121] 86,848 [117,744] 8 [203] 7 [178] 25 [635] 3,200 [1,451] 8 [203.20] 3 [76.20] 65⁄8 Reg 32.00 [9,754] 300,000 [1,334,400] 1,621,565 [7,212,721] 98,490 [133,528] 8 [203] 7 [178] 25 [635] 3,550 [1,610] 81⁄4 [209.55] 3 [76.20] 65⁄8 Reg 32.00 [9,754] 350,000 [1,556,800] 1,819,384 [8,092,620] 115,418 [156,478] 8 [203] 8 [203] 25 [635] 4,000 [1,814] 81⁄2 [215.90] 3 [76.20] 65⁄8 Reg 32.00 [9,754] 350,000 [1,556,800] 1,846,269 [8,212,205] 115,418 [156,478] 8 [203] 8 [203] 25 [635] 4,500 [2,041] 91⁄2 [241.30] 3 [76.20] 75⁄8 Reg 32.50 [9,906] 500,000 [2,224,000] 1,654,172 [7,357,757] 152,802 [207,161] 8 [203] 8 [203] 25 [635] 5,600 [2,540]
Accelerator AP
Accelerator AP
The Accelerator AP impact tool is recommended whenever a Hydra-Jar AP tool is placed in the string. It operates automatically with the jar, increasing reliability and ease of use, while protecting the drillstring and surface equipment from damaging shock waves.
Maximum jarring impact in any hole profile
Used in conjunction with the Hydra-Jar AP double-acting hydraulic drilling jar, the Accelerator AP tool combines the advantage of jarring up, down, or up-and-down with hydraulic fluid for maximum jarring impact. By increasing the velocity of the mass applied to the jar, the Accelerator AP tool ensures optimum impact force from the Hydra-Jar AP tool. When used with the Hydra-Jar AP tool, fluid compression inside the Accelerator AP tool compensates for limited drillpipe stretch in shallow or crooked holes, providing stored energy so that the fish is hit hard regardless of depth. The tool also optimizes jar performance in extended-reach, directional, and horizontal wells, where the stored energy in the drillpipe is lost because of hole drag.
Efficient energy transfer
The Accelerator AP tool provides the same impact with less overpull at the jar. The hammer mass receives 100% transfer of the overpull.
Applications
■ Extended reach, directional, and horizontal
wells when drillpipe loses stored energy to hole drag
■ HPHT well conditions
■ Run in BHAs that include a Hydra-Jar AP
double-acting drilling jar
Benefits
■ Optimizes jar performance for recovery in
shallow or crooked holes
■ Impact force independent of hole condition
■ Creates up to twice as much impact force
than other tools for jarring up, down, or up and down
■ Protects the drillstring and surface
equipment from damaging shock waves
Hydra -Jar A P and Acce lerato r AP i mpac t force Hydra-Ja r AP impact f orce 0 50 100 150 200 100% 1,000 800 600 400 200 0
Maximum impact force, lbf
Actual applied load, lbf
Features
■ Fluid compression inside tool compensates
for limited drillpipe stretch in shallow wells, providing stored energy, creating maximum impact
■ Fullbore design minimizes pressure losses
and provides wireline tool compatibility
■ Operates automatically with the jar,
increasing reliability and ease of use
■ Efficient design ensures full overpull force
is delivered to the hammer section, creating maximum positive impact
■ Rated to 500 degF, optional ultra high
temperature seals rated to 650 degF
■ Seals are rated to 20,000 psi
■ Circulation rated to 10,000 psi
Accelerator AP offered in same size configurations as the Hydra-Jar AP drilling jar.
When run in combination with the Hydra-Jar AP jar or the HydraQuaker drilling jar, the Accelerator AP tool more than doubles the available impact force