Drilling Tools Catalog

Drilling Tools Catalog


Table of Contents BHA Drilling Tools Borrox AP Advanced Performance Sealed-Bearing Reamer . . . . . . . . . . . . . . . . . 1 .................................................. 3 Model 60 and 62 Rotary Reamer ........................................................................... 5 Shock Sub .............................................. 6 Diamond-Enhanced Insert Reamer Inline Reamer . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7 ............................................................... 8 Gauge-Indicator Sub ....................................................... 9 DOG Drilling On Gauge Sub . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10 Diamond-Enhanced Insert Stabilizer . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11 Double-Diamond Combo Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12 Integral Blade Stabilizer . . . . . . . . . . . . . . . . 13 Ezy-Change Type II Rig-Replaceable Sleeve-Type Stabilizer Neyrfor Traditional . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15 Neyrfor Delta . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 16 Neyrfor LC3 Turbodrill Locking Clutch . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 17

Drilling Impact Tools AP Impact System . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 18 Jar-Pact Program . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19 Data Acquisition Program . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19 Hydra-Jar AP . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 20 Accelerator AP . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 22 HydraQuaker . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 23 Hydra-TT Double-Acting Hydraulic Jar . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 24 Accelerator-TT Double-Acting Accelerator Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 25 Hydra-Stroke Bumper Sub . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 26 TMC Jar, Single-Acting Hydraulic Fishing Jar (Up Only) . . . . . . . . . . . . . . . . . . . . . 27 TMC Accelerator, Single-Acting Fishing Accelerator (Up Only) . . . . . . . . . . . . 28 TMC Bumper Fishing Bumper Sub . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 30 Hex Fishing Bumper Sub . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 31

Borehole Enlargement . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 32 Borehole Enlargement Introduction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 33 Rhino XC Reamer . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 34 Rhino XS Reamer . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 36 Predator Cutter Blocks Cement Cleanout Blocks . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 37 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 38 Rhino Stabilization System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 39 Fixed-Diameter Hole Openers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 40 Drilling-Type Underreamer . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 41 Reamaster-XTU Underreamer . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 42 Rock-Type Underreamer

BHA Drilling Tools

Borrox AP Advanced Performance Sealed-Bearing Reamer 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* milledprofile 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

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Medium to severely packed hole assemblies

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Extremely abrasive drilling conditions

Cap screws Cutter assembly Lower block

Shim (upper block only when required)

Borrox AP advanced performance sealed-bearing reamer

Benefits ■■

Available in all common hole sizes

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Reduce downhole torque caused by wellbore spiraling and doglegs

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Maintains borehole quality

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Maintains hole gauge in extreme conditions

Features ■■

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Blank ended manufacturing means the tool can be configured for near bit and string placement in the BHA

DEX cutter

RSX cutter

High-flow body increases annular total flow area (TFA) to improve hole cleaning Longer full-gauge cutting section enhances gauge maintenance

c

Proprietary seal endures high loads, temperatures, and rotary speeds to extend bearing life

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Three cutter assemblies allow customization for different applications

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Cutter assemblies changed safely and easily on rig floor

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KSX cutter

Optional real-time data connection for use with Schlumberger LWD tools

b

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.

a

Borrox AP advanced performance sealed-bearing reamer

1

Schlumberger BHA Drilling Tools

Borrox AP Advanced Performance Sealed-Bearing Reamer Borrox AP Specifications Body Diameter, Hole Size†, in in (a) 5.875 5.620 6.000 5.620 6.125 5.620 6.250 5.620 6.125 (large bore) 5.620 6.250 (large bore) 5.620 6.500 6.000 7.875 7.400 8.375 (6.5–in necks) 8.140 8.500 (6.5–in necks) 8.140 8.750 (6.5–in necks) 8.140 8.375 (7–in necks) 8.140 8.500 (7–in necks) 8.140 8.750 (7–in necks) 8.140 9.875 9.500 10.625 10.250 12.000 11.550 12.250 (8–in necks) 11.800 12.250 (10–in necks) 11.800 14.250 12.855 14.750 14.000 16.000 (10–in necks) 14.000 16.000 (11–in necks) 14.000 16.375 13.764 16.500 13.764 17.000 14.313 17.500 15.500 18.125 15.415 18.250 15.415 20.000 22.000‡

Bore Diameter, in

Cutter Size, in

1.250 1.250 1.250 1.250 1.500 1.500 1.250 2.250 2.250 2.250 2.250 2.250 2.250 2.250 2.813 2.813 2.813 2.813 2.813 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000 3.000

1.900 2.000 2.000 2.000 1.900 1.900 2.000 2.370 2.625 2.625 2.625 2.625 2.625 2.625 2.625 2.625 4.000 4.000 4.000 4.000 5.125 5.125 5.125 5.125 5.125 5.125 5.125 5.125 5.125 5.125

Tool Length, in (b) 77.000 77.000 77.000 77.000 77.000 77.000 77.000 87.000 87.000 87.000 87.000 87.000 87.000 87.000 82.000 87.000 112.000 112.000 112.000 112.000 112.000 112.000 112.000 112.000 112.000 112.000 112.000 112.000 112.000 116.000

Fishing Neck Length, in (c) 24.000 25.000 26.000 27.000 24.000 24.000 24.000 29.000 31.000 31.000 31.000 31.000 31.000 31.000 30.000 31.000 49.000 49.000 49.000 43.000 49.000 49.000 49.000 43.000 43.000 43.000 49.000 43.000 43.000 38.000

Fishing Neck Diameter, in 4.750 4.750 4.750 4.750 4.750 4.750 4.750 6.500 6.500 6.500 6.500 7.000 7.000 7.000 8.500 8.250 10.000 8.000 10.000 10.000 10.000 10.000 11.000 10.000 10.000 10.000 10.000 10.000 10.000 10.000

Estimated Body Weight, lbm 349 349 349 349 341 341 376 697 782 782 782 828 828 828 1,142 1,244 2,153 1,477 2,181 2,366 2,267 2,405 2,805 2,414 2,414 2,499 2,649 2,672 2,672 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, Bore Diameter, in Cutter Size, in in 8.500 with 5.50 FH Pins 8.000 3.400 2.000 12.250 with 6.62 FH Pins 11.688 4.250 2.620 12.250 with 7.62 H90 Pins 11.688 4.250 2.620 17.500 with 7.62 H90 Pins 15.500 4.250 5.125


Tool Length, in 61.000 58.000 59.000 62.500

Fishing Neck Length, in 8.500 8.000 8.500 8.500

Fishing Neck Diameter, in 6.875 8.500 9.000 9.500

Estimated Body Weight, lbm 475 781 833 1,183

2

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.

c

Durable construction

c

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

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High temperature conditions

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Medium to hard and hard formations

a b

a b

Benefits ■■

Cost effective design for many applications

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Flexible design enables many string placement options

Features ■■

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Large bearing area and open circulation (Model 60) enable highrotary speed Large diameter, carburized, hardened pins compose abrasionresistant bearing sections Non-sealed-bearing design is cost-effective for many applications

Three-point reamer

“Type Q” cutters’ hard-faced, carburized steel teeth deliver wearresistant reaming

Model 60 and 62 rotary reamer

Six-point reamer

“Knobby” cutters’ tungsten carbide inserts fracture rock


Model 60 and 62 Rotary Reamer Model 60 and 62 Rotary Reamer Specifications Reamer Bodies Complete (String or Bottom Hole)

Hole Size, in 41⁄8 45⁄8 43⁄4 55⁄8 57⁄8 6 61⁄8 61⁄4 61⁄2 75⁄8 77⁄8 83⁄8 81⁄2 85⁄8 83⁄4 91⁄2 95⁄8 97⁄8 105⁄8 11 12 121⁄4 133⁄4 143⁄4 15 171⁄2 181⁄2 20 24 26 337⁄8† †

Cutter Size, in 13⁄8 11⁄2 11⁄2 2 2 2 2 2 2 25⁄8 25⁄8 25⁄8 23⁄4 23⁄4 23⁄4 31⁄8 31⁄8 31⁄8 31⁄4 31⁄4 4 4 4 51⁄2 51⁄2 51⁄2 51⁄2 51⁄2 7 7 7

Bearing Pin Size, in 3 ⁄4 7 ⁄8 7 ⁄8 1 1 1 1 1 1 13⁄8 13⁄8 13⁄8 13⁄8 13⁄8 13⁄8 13⁄4 13⁄4 13⁄4 13⁄4 13⁄4 21⁄4 21⁄4 21⁄4 21⁄2 21⁄2 21⁄2 21⁄2 21⁄2 3 3 3

Bearing Blocks ID Size, in and Type 3 ⁄4 A 7 ⁄8 A 7 ⁄8 B 1A 1C 1A 1B 1C 1E 13⁄8 A 13⁄8 C 13⁄8 A 13⁄8 A 13⁄8 B 13⁄8 C 13⁄4 A 13⁄4 B 13⁄4 D 13⁄4 A 13⁄4 D 21⁄4 C 21⁄4 E 21⁄4 E 21⁄2 A 21⁄2 C 21⁄2 E 21⁄2 A 21⁄2 M 3A 3C 3C

Maximum Body Diameter, in (a) 33⁄4 41⁄4 41⁄4 5 5 51⁄2 51⁄2 51⁄2 51⁄2 7 7 73⁄4 73⁄4 73⁄4 73⁄4 83⁄4 83⁄4 83⁄4 91⁄2 91⁄2 101⁄2 101⁄2 113⁄4 123⁄4 123⁄4 15 163⁄8 163⁄8 22 22 30

Body Bore, in 1 1 1 1 1 11⁄4 11⁄4 11⁄4 11⁄4 15⁄8 15⁄8 17⁄8 17⁄8 17⁄8 17⁄8 21⁄4 21⁄4 21⁄4 21⁄4 21⁄4 213⁄16 213⁄16 213⁄16 213⁄16 213⁄16 3 3 3 3 3 3

Three-Point Reamer (b) (c) Weight with Cutters, lbm 50 19 100 50 19 130 50 19 130 64 25 230 64 25 230 64 25 260 64 25 260 64 25 260 64 25 260 79 33 474 79 33 474 80 34 575 80 34 575 80 34 575 80 34 575 90 39 785 90 39 785 90 39 785 91 39 950 91 39 950 112 501⁄2 1,088 112 501⁄2 1,088 112 501⁄2 1,445 112 49 1,705 112 49 1,705 112 47 2,400 112 47 2,650 112 47 2,650 122 50 3,900 122 50 3,900 130 42 8,900

Six-Point Reamer (b) (c) Weight with Cutters, lbm 86 32 190 86 32 250 86 32 250 105 32 450 105 32 450 105 32 510 105 32 510 105 32 510 105 32 510 121 35 960 121 35 960 122 36 1,160 122 36 1,160 122 36 1,160 122 36 1,160 135 37 1,600 135 37 1,600 135 37 1,600 137 40 1,900 137 40 1,900 155 451⁄2 2,230 155 451⁄2 2,230 155 431⁄2 2,600 155 431⁄2 2,600 1 155 43 ⁄2 2,600 164 45 5,100 164 45 5,100 164 45 5,100 164 45 5,100 164 45 5,100 164 45 5,100

Model 60 33 7⁄8–in tool available in four-cutter configuration only.

rdering instructions, please specify: O • 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


4

Shock Sub 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 bidirectionalspring 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.

Benefits ■■ ■■

Extended connection life

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Reduced shock loads on surface equipment

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Lower drilling cost per foot

Features ■■ ■■

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Directional drilling: hard formations, horizontal sections, directionally drilled crossings

Longer life for the cutting structure and bearings because of reduced impact loads

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Applications

Drilling competent sediments in straight holes with roller cone or hammer bits

Increased ROP

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

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Belleville spring stack engineered for optimal WOB

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Milling operations: sections, windows, casing

Spring rate adjustable to meet application-specific requirements

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Underreaming and hole opening

Seals isolate internal components from drilling fluid

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Tool needs no activation

Coiled tubing drilling operations

Shock Sub Specifications Overall Diameter, in Internal Diameter, in [mm] [mm] 4.75 [121] 5.0 [127] 6.5 [165] 8.0 [203] 9.5 [241] 12.0 [305] 14.0 [356]

1.75 [44] 1.75 [44] 2.25 [57] 3.00 [76] 3.00 [76] 3.25 [83] 3.25 [83]

Tool Joint Connection, in

Tensile Yield, lbf [N]

Torsional Yield, lbf.ft [N.m]

31⁄2 IF

415,000 [1,846,000] 589,000 [2,620,000] 800,000 [3,559,000] 1,100,000 [4,893,000] 1,800,000 [8,006,000] 2,300,000 [10,230,000] 2,300,000 [10,230,000]

17,500 [23,700] 31,000 [42,000] 57,000 [77,200] 84,000 [113,900] 150,000 [203,300] 250,000 [339,000] 400,000 [542,300]

XT39 41⁄2 IF 41⁄2 XH 65⁄8 Reg 75⁄8 Reg 75⁄8 H90 85⁄8 H90

Approximate Weight, lbm [kg] 600 [270] 800 [360] 1,300 [590] 1,800 [817] 2,700 [1,225] 4,500 [2,041] 6,200 [2,812]

Length, ft [m] 11.5 [3.50] 11.5 [3.50] 12.0 [3.68] 13.5 [4.12] 13.5 [4.12] 13.8 [4.21] 14.3 [4.36]

Shock Sub

5


Diamond-Enhanced Insert Reamer 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.

Tool length

Applications ■■

Rib length

Removing ledges and opens under-gauge portions of build sections for directional work

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Removing keyseats

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High-temperature reaming

Benefits ■■

Produces high-quality full-gauge wellbores

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Allows greater circulation

Features ■■

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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 mediumhard formations

Diamond-enhanced insert reamer

Spiral body facilitates high-circulation rates and efficient evacuation of cuttings Tapered body profile enables reaming downward and upward

Diamond-Enhanced Insert Reamer Specifications Hole Size, in Rib Length, in Bore Diameter, in 6 18 2 22 21⁄4 77⁄8 22 21⁄4 81⁄2 3 22 21⁄4 8 ⁄4 7 22 213⁄16 9 ⁄8 1 1 23 ⁄2 3 12 ⁄4

Neck Diameter, in 43⁄4 61⁄4 63⁄4 63⁄4 7 8

Tool Length, in 60 64 64 64 66 72

Approximate Weight, lbm 265 530 635 655 755 1,190

Additional sizes available upon request. Available in non-magnetic material by special order only. Ordering instructions, please specify: • Hole size • Drill collar or fish neck diameter • Bore ID • Size, type and location of connections


6

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

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Clearing cutting beds from horizontal shale wells

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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

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Four blades for reaming efficiency

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PDC buttons on taper effectively cleans borehole

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Standard carbide buttons on gauge pad reduce rotating torque and drag; mixed cutter type (PDC or carbide) available on gauge pad

Inline Reamer Specifications OD, in [mm] Minimum ID, in [mm] Gauge OD, in [mm] Fishing neck OD, in [mm] Fishing neck length, in [mm] Cutter type Gauge pad buttons Overall length, in [mm] Number of blades Up connections Down connections

7

4.75 [120.7] 2.6875 [68.3] 5.875 [149.2] 4.75 [120.7] 18–24 [457.2–609.6] PDC on taper Carbide or PDC 60–66 [1524–1676.4] 4 3½ IF 3½ IF

Inline reamer


Gauge Indicator Sub 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 undergauge holes

Benefits ■■

Reduces reaming time

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Extends bit life

Features ■■

Configuration extends bit life by centering bit in wellbore

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Cutting design delivers a smoother, high-quality wellbore

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Gauge indicator sub

Short design facilitates placement at the bit, regardless of directional system Type 300 hardfacing ensures long life in abrasive environments


8

DOG Drilling On Gauge Sub 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.

Benefits ■■

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Can be placed between bit and mud motor for directional applications Provides reaming and contact behind bit, wiping out ledges as drilling progresses

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Stabilizes BHA assembly

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Increases drilling performance

Applications

Features

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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 Specifications Hole Size, in Connection Size Bore Diameter, and Type in 43⁄4 27⁄8 Reg 11⁄4 31⁄2 Reg 11⁄4 57⁄8 11⁄4 6 31⁄2 Reg 31⁄2 Reg 11⁄4 61⁄8 31⁄2 Reg 11⁄4 61⁄4 1 1 3 ⁄2 Reg 11⁄4 6 ⁄2 3 1 3 ⁄2 Reg 11⁄4 6 ⁄4 3 1 4 ⁄2 Reg 21⁄4 7 ⁄8 1 1 4 ⁄2 Reg 21⁄4 7 ⁄2 7 1 4 ⁄2 Reg 21⁄4 7 ⁄8 1 1 4 ⁄2 Reg 21⁄4 8 ⁄4 3 1 4 ⁄2 Reg 21⁄4 8 ⁄8 7 1 4 ⁄2 Reg 21⁄4 8 ⁄16 1 1 4 ⁄2 Reg 21⁄4 8 ⁄2 3 1 4 ⁄2 Reg 21⁄4 8 ⁄4 1 21⁄4 9 4 ⁄2 Reg 1 5 6 ⁄8 Reg 3 9 ⁄2 65⁄8 Reg 3 97⁄8 65⁄8 Reg 3 105⁄8 3 11 65⁄8 Reg 65⁄8 Reg 3 115⁄8 65⁄8 Reg 3 121⁄8 65⁄8 Reg 3 121⁄4 75⁄8 Reg 33⁄8 143⁄4 75⁄8 Reg 33⁄8 151⁄2 33⁄8 16 75⁄8 Reg 75⁄8 Reg 3 171⁄2 3 20 75⁄8 Reg 3 22 75⁄8 Reg

Shoulder to Shoulder Length, in 61⁄2 73⁄8 73⁄8 71⁄2 71⁄2 77⁄8 81⁄8 81⁄4 73⁄8 8 83⁄8 83⁄8 83⁄8 83⁄8 89⁄13 91⁄2 85⁄8 91⁄8 97⁄8 103⁄8 101⁄2 111⁄2 113⁄8 217⁄8 221⁄4 225⁄8 241⁄8 263⁄4 287⁄8

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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

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No moving parts to wear or fail ensures reliability

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Short body facilitates reaming directly at bit

Rib Length, in 57⁄8 67⁄16 63⁄8 67⁄16 67⁄16 65⁄8 65⁄8 65⁄8 63⁄8 65⁄8 67⁄8 71⁄8 7 7 71⁄4 67⁄8 77⁄8 73⁄4 81⁄8 83⁄8 87⁄8 7 9 93⁄4 71⁄4 101⁄8 105⁄8 83⁄5 9

Weight, lbm 39 51 54 57 61 66 71 64 79 88 95 102 107 111 115 110 112 159 181 187 174 214 206 563 523 578 706 980 1,122

Shoulder to shoulder length

Rib length

DOG drilling on gauge sub

Unless otherwise requested, nominal gauge diameter for this product is OD +0 in, -1⁄32 in

9


Diamond-Enhanced Insert Stabilizer 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

Tool length

Benefits

a b

■■

Dependable reaming in hard or abrasive formations

■■

Maintains full-gauge borehole

Blade length

Features ■■

■■

DEI inserts maintain hole gauge, extend stabilizer life and improve BHA performance Insert profile reduces drillstring torque and drag

DEI stabilizer

Diamond-Enhanced Insert Stabilizer Specifications Hole Size, in Overall Length, Neck Overall in Diameter, in 75 61⁄2 83⁄8 75 61⁄2 81⁄2 5 77 8 10 ⁄8 81 8 121⁄4 81 91⁄2 121⁄4


Top Neck Length, in 30 30 30 30 30

Bottom Neck Length, in 24 24 24 24 24

Blade Length, in (a) 16 16 16 16 16

Blade Length, in (b) 6 6 6 6 6

10

Double-Diamond Combo Tool 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.

Benefits ■■

■■

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 diamondenhanced 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 ■■

■■

■■

■■

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

Blade length Tool length

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

DEI placement

Drilling crooked holes that call for packedhole assemblies Maintaining the tangent section of a well during directional drilling

Double-Diamond Combo Tool Specifications Hole Size, in Blade Length, in 12 77⁄8 12 81⁄2 12 83⁄4 18 121⁄4

Double-diamond combo tool

Bore Diameter, in 21⁄4 21⁄4 213⁄16 3

Neck Diameter, in 61⁄4 63⁄4 63⁄4 91⁄2

Tool Length, in 65 65 65 76

Approximate Weight, lbm 900 980 990 2,000

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

11


Integral Blade Stabilizer 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.

Applications ■■

■■ ■■

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

■■

Applications requiring the placement of stabilizers in the BHA and upper drill-collar string to reduce vibration in drill collars Works in most formations Available in bottomhole and string design, runs anywhere in BHA

b

a

Prevents wall damage while ensuring maximum circulation

Features ■■

■■

One-piece construction

The integral blades and tool body eliminate the risk of leaving components or pieces in the hole.

Pendulum assemblies


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.

Packed-hole assemblies that require the placement of multiple stabilizers throughout the three zones of stabilization

■■

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

Integral Blade Stabilizer Specifications Hole Size Range, in Drill Collar Overall Diameter Range, in

Bore, in

Overall Length, in (a)

Blade Length, in (b)

4 ⁄4 57⁄8 63⁄4 77⁄8 81⁄2–83⁄4 91⁄4–97⁄8 105⁄8 12–121⁄4 171⁄2 24 28

1 ⁄2 13⁄4 21⁄4 213⁄16 213⁄16 213⁄16 213⁄16 3 3 3 3

62 62 64 64 65 66 66 72 76 91 95

10 10 12 12 13 13 13 15 15 20 20

3

3 ⁄4 43⁄4 51⁄2 61⁄2 63⁄4–7 71⁄4–81⁄4 81⁄4 81⁄4–91⁄2 10 10 10 3

1

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. Ordering instructions, please specify: • Hole size • Drill collar or fish neck diameter • Bore ID • Size, type and location of connections • String or bottomhole stabilizers • Dressed with Type 300 Hardfacing or Type 200 TCI inserts • Cast- or pressed-steel thread protectors


12

Ezy-Change Type II Rig-Replaceable Sleeve-Type Stabilizer The Ezy-Change* type II stabilizer is designed around a rugged, onepiece 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.

Sleeve dressed with Type 300 hardfacing

Mild to medium packed hole assemblies

■■

Pendulum assemblies

■■

Directional drilling assemblies

■■

Harmonic vibration control


Reduces the need to maintain large mandrel inventory on location

Sleeve dressed with Type W hardfacing

Upset diameter

Applications ■■

Sleeve dressed with Type 200 tungsten carbide inserts

Drill collar diameter

Fishing neck length

Small footprint enables placement in remote or spaceconstrained 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

Nominal overall length

Bottom neck diameter

Ezy-Change type II rig-replaceable sleeve-type stabilizer

13


Ezy-Change Type II Rig-Replaceable Sleeve-Type Stabilizer Sleeve Specifications Hole Size, in Tool Series 62 65 62 65 62 65 77 85 96 77 85 96 77 85 96 96 96 96 96

81⁄2 83⁄4 97⁄8 121⁄4

143⁄4

171⁄2 22 24 26 28

Mandrel Specifications Tool Sleeve Hole Series Size Range, in

62 65 77 85 96 96

81⁄2–97⁄8 81/2–97⁄8 121⁄4–171⁄2 121⁄4–171⁄2 143⁄4–20 22–28

Drill Collar Size Range, in

Length, in

Body Diameter, in

Blade Length, in

Weight, lbm

Recommended Makeup Torque, lbm.ft

61⁄4–63⁄4 61⁄2–71⁄4 61⁄4–63⁄4 61⁄2–71⁄4 61⁄4–63⁄4 61⁄2–71⁄4 73⁄4–81⁄4 81⁄2–9 9–10 73⁄4–81⁄4 81⁄2–9 9–10 73⁄4–81⁄4 81⁄2–9 9–10 9–10 9–10 9–10 9–10

14 14 14 14 14 14 14 14 14 18 18 18 18 18 18 22 32 32 32

71⁄2 71⁄2 71⁄2 71⁄2 73⁄4 73⁄4 91⁄4 10 11 11 11 11 11 11 11 12 12 12 12

12 12 12 12 11 11 11 11 11 14 14 14 12 12 12 12 16 16 16

70 80 75 85 85 95 140 130 110 330 300 270 370 340 310 1,780 2,050 2,110 2,190

4,500–5,500 3,500–4,500 4,500–5,500 3,500–4,500 4,500–5,500 3,500–4,500 7,000–8,000 9,000–10,000 10,000–12,000 7,000–8,000 9,000–10,000 10,000–12,000 7,000–8,000 9,000–10,000 10,000–12,000 10,000–12,000 10,000–12,000 10,000–12,000 10,000–12,000

Drill Collar Upset Diameter, (Fishing Neck) in Diameter, in

Bottom Neck Diameter, in

Overall Length, Fishing Neck Length in

61⁄4–63⁄4 61⁄2–71⁄4 73⁄4–81⁄4 81⁄2–9 91⁄2–10 91⁄2–10

61⁄4 61⁄2 73⁄4 81⁄2 95⁄8 95⁄8

65 65 66 66 66 90

71⁄2 73⁄4 91⁄4 97⁄8 11 11

String (Box Up), in 27 27 27 27 27 27

Bottom Hole (Pin Up), in 22 22 22 22 22 22

Weight, lbm

475 575 800 1,000 1,200 1,780

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) • Connections • String or bottomhole • Desired blade dressing: Type 300, Type 200 or Type W


14

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 diamondbearing pack design reduces vibration and noise, which can interfere with downhole measurement tools.

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.


Components ■■

Power section

■■

Rig-interchangeable stabilizers

■■

Pin down straight- or steerablebearing section

Available Tool Sizes

Directional drilling High-pressure, high-temperature (HPHT) drilling

■■

27⁄8 in

■■

33⁄8 in

Straight-hole drilling

■■

■■

43⁄4 in

Geothermal drilling

■■

■■

65⁄8 in

Underbalanced drilling

■■

■■

71⁄4 in

Single- or two-phase fluids

■■

■■

91⁄2 in

Benefits

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.

■■

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

Interchangeable mid-body stabilizer

PDC thrust bearings

Flexible titanium shaft Interchangeable lower-body stabilizer Rotor and stator blades

Adjustable bent housing

Neyrfor turbodrill

15


Neyrfor Delta 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.

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 diamondbearing pack design reduces vibration and noise, which can interfere with downhole measurement tools.

■■

■■ ■■

Neyrfor Traditional

Neyrfor Delta

Directionally drills curved, horizontal, and tangent applications High-pressure, high-temperature (HPHT) directional drilling

■■

Power section Engineered Neyrfor Delta Series directional stabilizers

■■

Pin down steerable-bearing section

■■

Power and Bearing Section

■■

43⁄4 in

■■

65⁄8 in

■■

91⁄2 in

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 ■■

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

■■

Available Tool Sizes

Applications ■■

Components

■■

Shortest bit to bend in class Proprietary engineered stabilizer placement and profile software

■■

Concentric-balanced design

■■

Fluid-connect drive system

Neyrfor Traditional

Neyrfor Delta

Neyrfor Delta stabilizers offer greater flow-by area and less surface contact area than standard turbodrill stabilizers.


16

Neyrfor LC3 Turbodrill Locking Clutch 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* highperformance 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.

Locking clutch pawl

Housing

In this cutaway view of the locking clutch system, the pawl is disengaged: its position during drilling.

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


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 ■■

■■

17

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


Drilling Impact Tools

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


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

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.

18

Schlumberger Drilling Impact Tools

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.


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.

Jar-Pact program

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


Data acquisition transducers

19

Hydra-Jar AP 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 hightemperature 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.

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

Detent system

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

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 drilling jar expands options for drilling, coring, cementing, testing, fishing, workover, and remedial operations.

20

Hydra-Jar AP


Hydra-Jar AP Hydra-Jar AP Specifications Outer Inner Tool Joint Diameter, Diameter, Connection in in [mm] [mm]

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]


21

Accelerator AP

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.

1,000

Maximum impact force, lbf

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.

800 600 nd Pa rA a J adr Hy

400

P ar A ra-J Hyd

200 0

AP tor ra e l ce Ac

0

50

e rc t fo ac p 100% im

e forc act imp

100

150

200

Actual applied load, lbf

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

Features ■■

■■

■■

■■

Efficient energy transfer

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

The Accelerator AP tool provides the same impact with less overpull at the jar. The hammer mass receives 100% transfer of the overpull.

■■

Applications

Accelerator AP offered in same size configurations as the Hydra-Jar AP drilling jar.

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■■ ■■

Extended reach, directional, and horizontal wells when drillpipe loses stored energy to hole drag

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Seals are rated to 20,000 psi

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HPHT well conditions Run in BHAs that include a Hydra-Jar AP double-acting drilling jar

Benefits ■■

■■ ■■

■■

■■

22

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

Accelerator AP

Recommended whenever drilling jar is placed in drillstring


HydraQuaker Re-engineered to deliver 300% more impact force, the HydraQuaker* hydraulic drilling jar’s advanced capability can be traced to the 50 years of experience and impact tool excellence that defined Houston Engineers, developer of the Hydra-Jar AP double-acting hydraulic drilling jar. The new generation HydraQuaker jar’s highly effective detent system ensures more consistent loading and firing of the jar over a wide range of borehole conditions. Designed for cost-effective operation in highvolume environments, the jar is easy to dress, extremely durable, offers dependable hitting performance in any application, and requires little maintenance.

Dependable and adjustable force

repeatedly, ensuring consistent impact to the stuck point regardless of downhole conditions.

Efficient drillstring activation

Once an impact has been delivered, the driller simply raises or lowers the drillstring, and the proprietary metering mechanism resets the HydraQuaker jar to deliver the next impact. There is no need to circulate or cool down, because the jar’s proprietary design enables it to endure high pressures and operating temperatures of up to 300 degF and 450 degF when equipped with its optional hightemperature seals.

Applications ■■

The HydraQuaker jar is capable of higher overpull and impact than conventional impact tools of the same size. Because its impact action does not require buildup torque for firing, its long free stroke maximizes impact, producing consistent and effective jarring force. The HydraQuaker jar’s impact action is fully adjustable downhole: Increasing the upward pull on the drillstring causes the tool to fire up, and slacking off causes the tool to fire down. It can be run in tension or compression, and its large piston area prevents automatic cocking or firing while pumps are operating normally. In addition, the jar’s flex subs provide tool joint flexibility for passing through high dogleg severity intervals.

Consistent force despite downhole conditions

■■

High-impact operations

■■

High-temperature operations

■■

Workover operations

Advantages ■■

■■

■■

■■

■■

■■

The HydraQuaker jar’s unique metering process compensates for the decrease in detent cylinder oil viscosity as the jar is fired

Drilling formations that cause drillpipe or other components to stick

■■

Long free stroke delivers maximum impact

The latest generation HydraQuaker features upgrades to the detent system (above), improving impact force more than 300%.

Flex subs enable conveyance through high dogleg severity intervals Jar can be run in tension or compression Large piston area prevents automatic cocking or firing with pumps operating normally Proprietary detent System ensures consistent impact in 300-degF and 450-degF conditions with optional high-temperature seals

HydraQuaker Specifications Tool OD, in [mm]

4.75 [121]

6.25 [159]

6.5 [165]

8 [203]

Tool ID, in [mm] Tool joint connection Maximum detent working load, lbf [N] Tensile yield strength, lbf [N] Torsional yield strength, lbf.ft [N.m]

2.25 [57] 3½ IF 90,000 [400,340] 452,737 [2,013,875] 19,116 [25,918]

2.75 [70] 4½ IF 185,000 [822,921] 761,980 [3,389,456] 41,315 [56,015]

2.75 [70] 4½ IF 185,000 [822,921] 916,152 [4,075,247] 56,395 [76,461]

3 [76] 65⁄8 Reg 300,000 [1,334,466] 1,302,363 [5,793,199] 102,056 [138,369]

Tool weight, lbm [kg]

1,800 [483]

2,400 [894]

2,600 [969]

3,800 [1,550]


Piston retainer Detent piston

Proprietary metering mechanism enables drillstring activation

HydraQuaker

23

Hydra-TT Double-Acting Hydraulic Jar The Hydra-TT* double-acting hydraulic jar is a slimhole impact tool designed to free equipment stuck downhole. Jarring force is delivered on up and down strokes, and the tool’s small diameter makes it ideal for use in coiled tubing (CT) operations, snubbing, and smalldiameter rotary drilling and fishing applications. The Hydra-TT doubleacting hydraulic jar has a robust design, high materials quality, and comprehensive quality requirements to ensure reliable performance in even the harshest downhole conditions. Because the Hydra-TT double-acting hydraulic jar is capable of torque transmission, it can be used with a downhole motor. The tool is equipped with premium seals for use in both high-temperature and high-pressure wells, and prolonged jarring can be accomplished with a temperature-compensated detent system. It also has a large bore to accommodate drop balls and flow release equipment below the tool.

Applications ■■

Milling, drilling, workover, remedial, or completion operations

■■

Vertical, deviated, ultradeep, and ultrahot wellbores

■■

Coiled tubing, snubbing, or concentric tubing work strings

Benefits ■■

Optimized recovery in slimhole jarring operations

■■

Dependable recovery in HPHT well conditions


■■

■■

Double-acting design delivers jarring force on up and down strokes Temperature compensated detent system enables prolonged jarring when required Large bore accommodates drop balls and flow release equipment below tool Maximum stroke length increases impact force, improving tool effectiveness

■■

Temperature rated to 500 degF

■■

Seals rated to 20,000 psi differential

■■


Hydra-TT doubleacting hydraulic jar

Hydra-TT Double-Acting Hydraulic Jar Specifications Overall Internal Tool Joint Overall Diameter, in Diameter, in Connection Extended Length 111⁄16

9

1

2 ⁄6

11

27⁄8

31

Tensile Yield Strength, lbf 56,000

Torsional Yield Strength, lbf.ft 850

Free Stroke Up, in

Free Stroke Down, in

Total Stroke, Tool Weight, in lbm

4

4

12

⁄16

1–in AMMT

⁄16

1 ⁄2–in AMMT

7 ft, 9 in

11,000

86,000

1,600

4

4

12

56

⁄32

23⁄8–in PAC

8 ft, 3 in

20,000

200,000

5,300

4

4

12

140

1

7 ft, 10 in

Maximum Detent Working Load, lbf 8,000

38

Ordering instructions, please specify: • Hole size • Drillstring component OD where tool will be used • Connection size and type

24


Accelerator-TT Double-Acting Accelerator Tool The Accelerator-TT* double-acting accelerator is a slimhole impactenhancement tool designed to multiply jar impact by providing or maximizing the stored energy source. It has a small diameter, making it ideal for coiled tubing (CT) operations, snubbing, and small-diameter rotary drilling and fishing applications. This accelerator also acts as a shock absorber, preventing impact damage to BHA components like CT connectors and back-pressure valves. It has a nitrogen-filled compression chamber that stores tool energy while reducing tool length, as well as a large bore to accommodate drop balls and flow release equipment below the tool.

Applications ■■

Recommended anytime jar is included in work string

■■

Milling, drilling, workover, remedial, or completion operations

■■

Vertical, deviated, ultradeep and ultrahot wellbores

■■

Coiled tubing, snubbing, or concentric tubing work strings

Benefits ■■

Optimized recovery in slimhole, higher-impact jarring operations

■■

Dependable recovery in HPHT well conditions

■■

Protects BHA components from impact damage

Features ■■

■■

■■

Nitrogen filled compression chamber stores tool energy while reducing tool length Large bore accommodates drop balls and flow release equipment below tool Maximum stroke length increases acceleration energy, improves tool effectiveness

■■

Temperature rated to 500 degF

■■

Seals rated to 20,000 psi

■■


■■

Functions as a shock absorber, preventing impact damage to BHA components such as coiled tubing connectors and back pressure valves

Accelerator-TT doubleacting accelerator

Accelerator-TT Double-Acting Accelerator Tool Specifications Overall Internal Tool Joint Overall Maximum Detent Diameter, in Diameter, in Connection Extended Working Load, lbf Length 111⁄16

9

1

2 ⁄6

11

27⁄8

31

8,000

Free Stroke Up, in

Free Stroke Down, in

Tool Weight, lbm

6

6

43

⁄16

1–in AMMT

⁄16

1 ⁄2–in AMMT

8 ft, 9 in

11,000

86,000

1,600

6

6

66

⁄32

23⁄8–in PAC

9 ft, 1 in

20,000

200,000

5,300

6

6

156

1

8 ft, 6 in

Tensile Yield Torsional Strength, Yield lbf Strength, lbf.ft 56,000 850

Ordering instructions, please specify: • Hole size • Drillstring component OD where tool will be used • Connection size and type • Hole temperature • Desired work loads


25

Hydra-Stroke Bumper Sub The Hydra-Stroke* bumper sub is a key drillstem component for deepwater drilling operations, where drillstring oscillation can be a problem. This tool provides 6 ft of reliable telescopic movement, without placing any limitations on drillstring torque capacity, tensile strength, or hydraulic capability.

Sub designed for reliability

The Hydra-Stroke bumper sub is fully balanced to the annulus and the mud pumps, making it completely reliable at any depth and in any drilling environment. The fully balanced feature eliminates the pump-open effect caused by internal pressure. The tool is rated for high temperature and pressure. Wellbore fluid cannot enter the drive section, improving reliability.

Applications ■■

■■

■■

Isolating drillstring assemblies from effects of wave motion on floating and semi-submersible rigs Providing drillstring travel in plug and abandonment operations when low level jarring or bumping is necessary Providing travel necessary to deploy knives for casing cutting operations

Benefits ■■

Enables jarring for recovery of tools at any depth offshore

■■

Operates dependably in HPHT well conditions

Features ■■

Delivers up to six feet of stroke to compensate for drillstring oscillation in offshore operations

■■

Remperature rated to 500 degF

■■


■■


■■

■■

Closed-drive system prevents ingress of wellbore fluid into drive section, improving reliability Fully balanced to eliminate pump-open effect caused by internal pressure

Hydra-Stroke bumper sub

Hydra-Stroke Bumper Sub Specifications, Full Balance Overall Internal Tool Joint Diameter, in Diameter, in Connection 51⁄4 21⁄4 31⁄2 API IF

Tensile Yield Strength, lbf 600,000

Torsional Yield Strength, lbf.ft 28,000

Total Stroke, in

61⁄2

23⁄4

41⁄2 API IF

964,207

58,300

8

3

6 ⁄8 Reg

1,571,980

114,000

5

Tool Weight, lbm

72

Closed Length, ft.in 35 ft, 3 in

72

32 ft, 8 in

3,200

72

36 ft, 2 in

3,340

1,500

Ordering instructions, please specify: • Hole size • Drillstring component OD where tool will be used • Connection size, type, right- or left-hand threads • Hole temperature • Tool diameter

26


TMC Jar, Single-Acting Hydraulic Fishing Jar (Up Only) The TMC Jar* single-acting hydraulic fishing jar combines optimal impact characteristics with highly durable construction for reliable fishing performance in harsh downhole environments. Tool seals are temperature rated to 500 degF and pressure rated to 20,000 psi. And, the temperature compensation system in the detent permits prolonged jarring without loss of impact force. Additionally, the TMC Jar’s closed-drive system prevents wellbore fluid from entering into the drive section improving tool performance and reliability.

Applications ■■

■■


Hydraulic metering system enables variable impact loads, controlled by degree of upward load applied by operator

■■

Rated to 500 degF

■■


■■


■■

■■

Any fishing operation: stuck pipe, packer retrieval, tubing removal, milling and debris recovery

Long free travel to optimize impact

■■

Temperature compensation system enables prolonged jarring when required Closed-drive system to prevent ingress of wellbore fluid into drive section improving reliability Interchangeable parts enable conversion between hydraulic jars and accelerator tools

Plug and abandonment operations, including pipe recovery, and wellhead removal

Benefits ■■

■■

Optimized jarring for fishing and other recovery operations Versatile and durable, endures HPHT well conditions

TMC Jar, single-acting hydraulic fishing jar (up only)

TMC Jar, Single-Acting Hydraulic Fishing Jar (Up Only) Specifications Tool OD, Tool ID, Tool Joint Overall Recommended in in Connection Length, Maximum Overpull ft.in Working Load, lbf 3 ⁄8 113⁄16 WMF 7 19,000 113⁄16

Total Stroke, in

Tensile Yield, lbf

Torsional Yield, lbf.ft

Tool Weight, lbm

9¾

56,000

800

75 54

13

1 ⁄16

9

⁄16

1 AM MT

5

17,000

7¼

69,000

750

21⁄4

1

⁄2

11⁄4 Reg

10

20,000

12

95,800

1,900

125

31⁄8

1

23⁄8 Reg

12

51,000

16

192,000

4,100

200

31⁄8

11⁄2

23⁄8 EUE

11

32,400

14

185,000

4,200

225

3 ⁄4

1 ⁄2

23⁄8 IF

12.2

59,000

16

257,000

6,600

240

3

3 ⁄4

2

2 ⁄8 EUE

11

38,000

16

233,000

7,400

325

41⁄4

2

27⁄8 IF

12.10

73,000

16

348,000

11,000

375

41⁄4

27⁄16

27⁄8 EUE

11

39,000

16

320,000

10,000

400

4 ⁄4

2

3 ⁄2 FH

13

90,000

16

422,000

14,000

425

43⁄4

21⁄4

31⁄2 IF

13.6

95,000

16

422,000

14,000

375

61⁄4

21⁄4

41⁄2 IF

15

180,000

18

900,000

50,000

950

1

6 ⁄2

2 ⁄4

4 ⁄2 IF

15

195,000

18

928,000

50,000

1,078

73⁄4

31⁄2

65⁄8 Reg

16

300,000

18

1,304,000

118,000

1,400

8

3 ⁄2

6 ⁄8 Reg

16

300,000

18

1,304,000

118,000

1,570

3

3

1

1

1

3

1

1

5

Ordering instructions, please specify: • Hole size • Connection size, type, and left- or right-hand threads • Tool diameter • Hole temperature • Desired operating load


27

TMC Accelerator, Single-Acting Fishing Accelerator (Up Only) The TMC Accelerator* single-acting fishing accelerator improves jar impact and delivers a supercharged blow directly above fish. Used in conjunction with the TMC Jar, the TMC Accelerator maximizes jar impact regardless of depth. As a result, it can replace pipe stretch as the energy source in shallow holes, or supplement the pipe stretch energy in deeper wells. The accelerator tool’s robust design, quality materials, and comprehensive QA requirements ensure reliable performance in the harshest fishing conditions.

Applications ■■

■■

Any fishing operation: stuck pipe, packer retrieval, tubing removal, milling and debris recovery Plug and abandonment operations, including pipe recovery and wellhead removal

Benefits ■■

■■

Reflects shock waves that propagate up work string and damage tool joints, top drives, and other surface components Interchangeable parts enables conversion between accelerator tools and hydraulic jars, reducing parts inventory and increasing flexibility

Features ■■

Delivers maximum blow directly above fish regardless of depth or wellbore environment

■■

Rated to 500 degF

■■


■■


■■

28

Closed drive system prevents ingress of wellbore fluid into drive section, improving reliability

TMC Accelerator, single-acting fishing accelerator (up only)


TMC Accelerator, Single-Acting Fishing Accelerator (Up Only) TMC Accelerator, Single-Acting Fishing Accelerator (Up Only) Specifications 113⁄16 Tool OD, in 113⁄16 9 3 Tool ID, in ⁄8 ⁄16 Tool Joint Connection 113⁄16 WFJ 1 AM MT Overall Length, ft.in 5.10 4.6 Tensile Yield, lbf 56,000 69,000 Torsional Yield, lbf.ft 800 750 8 71⁄4 Total Travel with Stop Sleeve†, in Rack Test‡, in @lbf 63⁄4 @ 6,000 41⁄4 @ 5,000 Oil Fluid, fl ozUS 2 2 7,500 6,000 Minimum overpull at 240 degF with jar and accelerator combination, lbf†† Maximum overpull at 240 degF with jar and 19,000 17,000 accelerator combination, lbf Tool Weight, lbm 60 46 TMC Accelerator, Single-Acting Fishing Accelerator (Up Only) Specifications 33⁄4 Tool OD, in 33⁄4 Tool ID, in 11⁄2 2 23⁄8 EUE Tool Joint Connection 23⁄8 IF Overall Length, ft.in 10.4 9 Tensile Yield, lbf 257,000 233,000 Torsional Yield, lbf.ft 6,600 7,400 † 3 11 ⁄8 12 Total Travel with Stop Sleeve , in Rack Test‡, in @lbf 10 @ 31,000 101⁄8 @ 16,000 Oil Fluid, fl ozUS 3 3 22,000 16,000 Minimum overpull at 240 degF with jar and accelerator combination, lbf†† Maximum overpull at 240 degF with jar and 59,000 38,000 accelerator combination, lbf Tool Weight, lbm 180 160 TMC Accelerator, Single-Acting Fishing Accelerator (Up Only) Specifications 61⁄4 Tool OD, in 43⁄4 1 21⁄4 Tool ID, in 2 ⁄4 1 Tool Joint Connection 3 ⁄2 IF 41⁄2 IF Overall Length, ft.in 11.10 12 Tensile Yield, lbf 422,000 900,000 Torsional Yield, lbf.ft 14,000 50,000 103⁄8 12 Total Travel with Stop Sleeve†, in 8 @ 37,800 83⁄4 @ 46,700 Rack Test‡, in @lbf Oil Fluid, fl ozUS 8 12 47,400 66,600 Minimum overpull at 240 degF with jar and accelerator combination, lbf†† Maximum overpull at 240 degF with jar and 95,000 107,000††† accelerator combination, lbf Tool Weight, lbm 325 800 Check stroke before loading the TMC Accelerator tool, if stroke varies, stop sleeves must be modified to obtain stroke as listed. ‡ Shop test at 70 degF for a nominal BHT of 240 degF, settings for other expected bottom hole temperatures are available upon request. †† Minimum overpull requirement for a jar-accelerator tool combination to obtain an efficient impact. ††† Maximum overpull can be increased in the shop, as the maximum increases, the minimum increases. †


21⁄4 ⁄2 11⁄4 Reg 8 95,800 1,900 10 71⁄2 @ 6,000 2 5,200

31⁄8 1 23⁄8 Reg 10 192,000 4,100 12 11 @ 29,000 3 19,000

31⁄8 11⁄2 23⁄8 EUE 9 185,000 4,200 101⁄2 10 @ 13,200 2 8,400

20,000

50,000

32,400

100

160

130

41⁄4 2 27⁄8 IF 10.8 348,000 11,000 111⁄4 95⁄8 @ 32,000 4 32,000

41⁄4 27⁄16 27⁄8 EUE 11.8 320,000 10,000 12 107⁄8 @ 19,000 3 15,000

43⁄4 2 31⁄2 FH 11 422,000 14,000 103⁄8 8 @ 36,000 8 54,000

73,000

39,000

90,000

300

268

350

61⁄2 21⁄4 41⁄2 IF 12 928,000 50,000 12 83⁄4 @ 46,700 12 66,600

73⁄4 31⁄2 65⁄8 Reg 13 1,304,000 118,000 12 10 @ 72,000 12 84,000

8 31⁄2 65⁄8 Reg 13 1,304,000 118,000 12 10 @ 72,000 12 84,000

107,000†††

150,000†††

150,000†††

900

1,200

1,350

1

Ordering instructions, please specify: • Hole size • Connection size, type, and left- or right-hand threads • Tool diameter • Hole temperature • Desired operating load

29

TMC Bumper Fishing Bumper Sub The TMC Bumper* fishing bumper sub combines maximum stroke length and high-torque transmission to enable the operator to bump up or down until fish are recovered. The TMC Bumper’s robust design, quality materials, and comprehensive quality requirements ensure reliable performance in the harshest downhole environments.

Applications ■■

■■

Suitable for all fishing operations: stuck pipe, packer retrieving, tubing removal, milling and debris recovery Plug and abandonment operations, including pipe recovery and wellhead removal

■■

Releases spears or overshots and shear pins

■■

Dislodges stuck string, acts as a feed-off tool in backoff operations

Benefits ■■

Sub’s stroke and torque enables operator to bump up or down until recovery is completed

Features ■■

Maximum stroke length and high-torque transmission

■■

Rated to 500 degF

■■


■■


■■

Closed-drive system prevents ingress of wellbore fluid into drive section, improving reliability

TMC Bumper fishing bumper sub

TMC Bumper Fishing Bumper Sub Specifications Tool OD, in Tool ID, in Tool Joint Connection 3 ⁄8 113⁄16 WFJ 113⁄16

Overall Length, ft.in 4.8

Total Stroke, in 93⁄4

Tensile Yield, lbf 56,000

Torsional Yield†, lbf.ft 800

Tool Weight, lbm 48

113⁄16

9

21⁄4

⁄16

1 AM MT

N/A

71⁄4

69,000

750

54

1

⁄2

11⁄4 Reg

6

12

95,800

1,900

75

3 ⁄8

1

2 ⁄8 Reg

7.1

16

192,000

4,100

125

31⁄8

11⁄2

23⁄8 EUE

6.11

14

185,000

4,200

100

3 ⁄4

1 ⁄2

2 ⁄8 IF

8.2

16

257,000

6,600

142

33⁄4

2

23⁄8 EUE

6.9

16

233,000

7,400

120

41⁄4

2

27⁄8 IF

8.3

16

348,000

11,000

232

4 ⁄4

2 ⁄16

2 ⁄8 EUE

9.5

16

320,000

10,000

260

43⁄4

2

31⁄2 API FH

8.8

16

422,000

14,000

337

43⁄4

21⁄4

31⁄2 API IF

9.6

16

422,000

14,000

314

1

6 ⁄4

1

2 ⁄4

3 ⁄2 API IF

9.8

18

900,000

50,000

794

61⁄2

21⁄4

41⁄2 API IF

9.8

18

928,000

50,000

890

7 ⁄4

1

3 ⁄2

6 ⁄8 API Reg

10.4

18

1,304,000

118,000

955

8

31⁄2

65⁄8 API Reg

10.4

18

1,304,000

118,000

1,110

1

3

1

3

†

1

7

3

3

7

1

5

Torsional yield is based on the tool joint connection.

30


Hex Fishing Bumper Sub The Hex* fishing bumper sub supplies durable and economical upward or downward bumping action for fishing operations. Full-torque transmission and circulation, through the tool, can be maintained constantly in any stroke position. The Hex sub’s robust design, quality materials, and comprehensive quality requirements ensure reliable performance in the harshest downhole environments.

Applications ■■

■■

■■

Delivers forceful blows in open and cased-hole recovery of fishing tools or safety joints Releases spears or overshots, shear pins, dislodges a stuck string, and acts as a feed-off tool in backoff operations Plug and abandonment operations where low level jarring may be required, or when cutting strings of casing


Higher torque transmission for back-off applications Only five major components, ensuring reliable performance and economical maintenance

Features ■■

Hexagonal mandrel ensures continuous torque transmission

■■

Up to 36–in stroke delivers solid-bumping action, upward or downward

■■

Fullbore design minimizes pressure losses and provides wireline tool compatibility Hex fishing bumper sub

Hex Fishing Bumper Sub Specifications Tool OD, in Tool ID, in Tool Joint Connection 3 ⁄8 113⁄16 WFJ 113⁄16

Total Closed Length, in 413⁄4

Total Stroke, in 20

Tensile Yield, lbf 99,000

Torsional Yield, lbf.ft 1,150

Tool Weight, lbm 25

31⁄2

1

23⁄8 Reg

621⁄2

20

193,000

5,200

95

3

3 ⁄4

1 ⁄2

2 ⁄8 IF

611⁄2

20

214,000

7,000

140

33⁄4

11⁄4

27⁄8 Reg

611⁄2

20

233,500

7,000

150

4 ⁄4

1 ⁄16

2 ⁄8 IF

59 ⁄8

20

352,000

12,800

140

43⁄4

2

31⁄2 IF

621⁄2

20

341,400

14,800

198

61⁄4

2

41⁄2 IF

641⁄2

20

813,900

33,000

390

1

6 ⁄4

1

2 ⁄4

4 ⁄2 IF

64 ⁄2

20

705,400

33,000

375

61⁄2

21⁄4

41⁄2 IF

645⁄8

20

760,000

34,000

415

3

6 ⁄4

3

2 ⁄4

5 ⁄2 Reg

67 ⁄4

20

790,000

38,000

455

73⁄4

31⁄2

65⁄8 Reg

711⁄8

20

900,000

40,000

655

8

31⁄2

65⁄8 Reg

711⁄4

20

1,200,000

40,000

717

1

1

15

3

7

1

1

1

1

1

Ordering instructions, please specify: • Hole size • Drillstring component OD where tool will be used • Connection size and type • Required stroke length


31

Borehole Enlargement

Borehole Enlargement Introduction Schlumberger Borehole Enlargement Combines Leading Technologies and Products

Schlumberger combined leading technologies to offer the industry’s best borehole enlargement tools: Rhino XC* on-demand hydraulically actuated reamer, Rhino XS* hydraulically expandable reamer, and Reamaster-XTU* forged cutter arm underreamer, were joined with innovative drilling products and software systems such as, Quad-D* dual-diameter drift drill bits, Quad-D directional drilling products, and IDEAS* integrated drillbit design platform and i-DRILL* engineered drilling system design. IDEAS platform enables analysis of wellbore enlargement components: Bits, reamers, and hole openers can be modeled to predict how they will behave in a drilling application. In the area of wellbore enlargement, IDEAS platform software enables Schlumberger engineers to tailor the Rhino XC reamer’s cutting structure for specific applications. The i-DRILL system accurately simulates the downhole behavior of drill bits, BHA components, and the drillstring and provides operators with a virtual picture that accurately depicts the dynamic downhole drilling environment. This capability enables designers to find optimum solutions for even the most complex drilling problems. Additionally, the simulation and analysis produces balanced drillbit and hole opening cutting structure design information to eliminate excessive vibrations. i-DRILL system design develops more accurate drilling program schedules with reduced risk of unplanned delays—saving the operator time and money.

Rhino XC cutter blocks are designed with the IDEAS platform.

Schlumberger complements this technology with DBOS* drill bit optimization system, which helps determine the appropriate combination of cutting structure, gauge protections, hydraulic configuration, and other optimizing features. Additionally, YieldPoint RT* drilling hydraulics and hole cleaning simulation program, HART* software for hydraulic optimization and i-DRILL for BHA design provide operators around the world with the capability to optimize drilling performance of their underreaming while drilling (UWD) operations. Beyond the latest technologies, Schlumberger can offer key information and management resources: Smith Bits DRS* drilling records system holds more than 3.5 million records from oil, gas, and geothermal wells from around the world. And, Schlumberger has the engineering expertise, experience, and worldwide resources to conduct comprehensive pre-job analysis, unmatched on-site performance, and post-job review. The combination of these technologies and resources form an advanced wellbore enlargement capability—delivering highquality wellbores regardless of the application.

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Schlumberger Borehole Enlargement

Rhino XC Reamer Unmatched underreaming performance and actuation control Building on Rhino XS reamer technology, the Rhino XC on-demand hydraulically actuated reamer enables a faster activation sequence than previous generations of hydraulically activated reamers. It efficiently enlarges wellbores for improved casing running, cementing clearance, and equivalent circulating density (ECD) control.

The Rhino XC reamer’s on-demand actuation system provides complete control of reamer cutter block deployment: It uses a flow activation system, which eliminates the need for time-consuming pumpdown device activation that can take up to 30 minutes. This allows the reamer to be placed below ID-restricted BHA components such as MLWD tools. And, with flow actuation control, the Rhino XC reamer provides the fastest cutter block activation and deactivation in the industry.

Reliability with borehole quality

As with all Rhino* integrated borehole enlargement systems, the Rhino XC reamer features the Z-Drive reamer cutter block deployment system to ensure cutter blocks are deployed during activation and retracted when the reamer is deactivated. The Rhino XC reamer is designed for a variety of formations where simultaneous drilling and hole-enlargement reliability are essential. The reamer’s one-piece, balanced design increases torque and loadcarrying capacity while reducing drilling-generated vibrations that produce undergauge and irregular boreholes.

Controls high-fluid volumes for effective cleaning

The Rhino XC reamer’s three nozzles can be changed to ensure optimum borehole cleaning and cuttings evacuation. The tool’s large bore handles high-fluid volumes with optimized distribution between the bit and cutter blocks, as well as the fluid requirements of rotary steerable systems and directional assemblies.

Durability with application flexibility

For extended footage, optional Predator* cutter blocks are available. Equipped with the ONYX* PDC cutters, Predator cutter blocks maximize ROP with cutters that remain sharper longer. ONYX cutters are more thermally stable for greater wear and impact resistance than other PDC cutters. And, single-set placement of each cutter on the cutting profile ensures a more stable and durable cutting structure. The Rhino XC reamer is designed to improve drilling performance over a wide range of applications: from hard and highly abrasive to Rhino XC Specifications Tool Series Overall Body Diameter, in 8000 9250 11625 13000 14250 16000 16000

8.00 9.25 11.63 13.00 14.25 16.00 17.375

Standard Fishing Neck Diameter, in 71⁄4 71⁄4 101⁄2 103⁄4 11 12 12


Enlarged Hole Size, in 9–101⁄4 101⁄4–113⁄4 13–15 141⁄2–161⁄2 153⁄4–181⁄4 171⁄2–20 181⁄2–22

Rhino XC reamer

interbedded difficult-to-drill formations. For unmatched reliability, efficiency, and control, the Rhino XC on-demand reamer is the industry’s premier borehole enlargement tool.

Applications ■■

BHA placement below ID restricted components, such as MLWD tools

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Boreholes requiring multiple reaming and nonreaming intervals

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Rotary BHA near-bit reamer placement

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Highly abrasive formation drilling

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Close-tolerance and expandable casing programs

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Extended-reach drilling and well profiles beyond 65°

Benefits ■■

Provides on-demand wellbore enlargement

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Improves drilling performance

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Ensures full-gauge concentric wellbores

Features ■■

Unlimited activations regardless of wellbore inclination

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Full-flow capability in reaming and nonreaming modes

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PDC cutter blocks rapidly deploy and retract

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Integrated jet nozzle effectively cleans boreholes

Minimum Pilot Internal Bore Internal Bore Hole Size, in Diameter, in Diameter without Nozzles, in 81⁄4 2.00 1.94 91⁄2 2.00 1.94 1 12 ⁄8 3.00 2.7 131⁄2 3.00 2.7 141⁄2 3.00 2.7 161⁄2 3.00 2.7 171⁄2 3.00 2.7

Increased Tool Length Due to Actuator, in 38.6 38.6 59 59 59 59 59

Sub Outer Maximum Diameter, in Flow Rate, galUS/min 7.25 750 7.25 750 11 1,700 11 1,700 11 1,700 11 1,700 11 1,700

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Rhino XS Reamer The rugged, precision-engineered Rhino XS reamer is the industry’s premier hydraulically expandable borehole enlargement tool, demonstrating superior reliability in 1,000s of runs worldwide. The reamer effectively enlarges wellbores up to 25% for improved casing running, cementing clearance, and equivalent circulating density (ECD) control. The tool is effective in a variety of formations where simultaneous drilling and hole enlargement reliability is essential. The Rhino XS reamer’s one-piece, balanced design increases torque and load carrying capacity, while reducing drilling-generated vibrations that produce undergauge and irregular boreholes.


In place of cutter arms, the Rhino XS reamer features a patented Z-Drive* reamer cutter block deployment system. This system traverses the cutter blocks to a pre-selected diameter and hydraulically clamps them into position. The parallel tongue and grove actuation design of the Z-Drive system ensures reliable cutter block deployment and retraction.

Drilling extended intervals with advanced rotary steerable systems (RSS)

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Extended-reach drilling

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Back reaming in loosely consolidated formations

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Drilling highly abrasive formations

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Close-tolerance and expandable casing programs

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Reliable hydraulically expandable reamer

The Rhino XS reamer is hydraulically activated and deactivated by pumping fluid through the drillstring and into the tool’s piston bore. A ball-drop activation/deactivation mechanism increases differential pressure when the first ball is dropped by restricting the tool bore, shearing the shear pins and deploying the cutters; pressure indicators at the surface signal full cutter deployment. For applications that require circulation with the cutter blocks in the closed position, an optional double ball drop (DBD) is available. The reamer’s activation/deactivation mechanism prevents fluid flow from deploying cutters during shoe track drilling or whenever circulation is necessary to help avoid stuck BHAs or casing damage.

Deepwater operations

Optimizes tubular programs, achieving higher production rates at lower cost


Reliable hydraulic actuation ensures fullgauge concentric wellbores Aggressive PDC cutter blocks for higher ROP in an array of formation types

Features ■■

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Dependable cutter block retraction avoids stuck BHAs and casing damage Integral back-reaming capability ensures construction of fulldiameter wellbore Integrated jet nozzle and flow paths improve clean out while drilling

The Rhino XS reamer has three changeable nozzles to ensure optimum cleaning and cuttings evacuation. The tool’s large bore handles high fluid volumes with optimized distribution between the bit and cutter blocks. This high-fluid capability also accommodates the fluid requirements of rotary steerable systems and directional assemblies.

Upper cap Spring retainer Spring cover Stop ring

Spring

Predator cutter block

Drive ring

Drive ring retainer

Nozzle Piston Lower cap Lower mandrel cap

The DBD deactivation option is used to deactivate the Rhino Reamer while allowing full flow to drill ahead or circulate when POOH with the reamer closed.

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Rhino XS reamer


Rhino XS Reamer Rhino XS Reamer Specifications Tool Series Overall Body Diameter, in 3500 3.50 4000 4.00 4500 4.50 5500 5.50 5625 5.62 5800 5.80 6125 6.13 6375 6.38 7300 7.25 8000 8.00 9250 9.25 10000 10.00 10375 10.38 11625 11.63 13000 13.00 14250 14.25 16000 16.00 16000 17.375 17500 17.50


Standard Fishing Neck Diameter, in 31⁄2 4 41⁄2 51⁄4 51⁄4 51⁄4 53⁄8 53⁄8 61⁄4 71⁄4 71⁄4 81⁄2 81⁄2 101⁄2 103⁄4 11 12 12 12

Enlarged Hole Size, in 4–41⁄2 41⁄2–51⁄2 43⁄4–53⁄4 61⁄2–7 61⁄2–7 61⁄2–73⁄8 7–71⁄2 7–8 8–9 9–101⁄4 101⁄4–113⁄4 11–121⁄2 113⁄4–131⁄2 13–15 141⁄2–161⁄2 153⁄4–181⁄4 171⁄2–20 181⁄2–22 211⁄2–24

Minimum Pilot Hole Size, in 33⁄4 41⁄4 43⁄4 53⁄4 57⁄8 61⁄8 63⁄8 63⁄4 71⁄2 81⁄4 91⁄2 101⁄2 107⁄8 121⁄8 131⁄2 141⁄2 161⁄2 171⁄2 181⁄8

Internal Bore Diameter, in 0.875 0.875 1.125 1.25 1.38 1.38 1.38 1.38 1.50 2.00 2.00 2.50 2.50 3.00 3.00 3.00 3.00 3.00 3.00

Maximum Thru Flow, gpm 141 141 230 230 350 350 350 350 500 750 750 1200 1200 1700 1700 1700 1700 1700 1700

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Predator Cutter Blocks Rhino XC on-demand reamers and Rhino XS reamers can be equipped with Predator cutter blocks, which employ the latest technological advances.

Faster ROP and fewer trips

Predator* cutter blocks use ONYX* PDC cutters, which are more thermally stable, as well as more wear- and impact-resistant than conventional PDC cutters. Extensive testing and analysis is used to optimize every step in the manufacture of these cutters, resulting in improved performance over a wide range of applications, from hard, highly abrasive to interbedded, difficult-to-drill formations. The cutters remain sharp longer, translating into more footage drilled at maximum ROP and substantially reduced drilling costs. Moreover, the single-set cutter placement, which means that each cutter is in a unique location on the cutting profile, results in a more stable and durable reamer cutting structure.

Optimized design

The advanced cutting structure is optimized for maximum ROP with minimum vibration using the industry’s most advanced drillstring dynamics modeling software, IDEAS. This brings application-specific cutting structures to borehole enlargement and avoids damaging vibrational loading of the cutters.

Predator cutter block

The reamer placement and operating parameters are also optimized for performance with the rest of the BHA components. Combining the best cutter with the most dynamically stable design delivers maximum performance in multiple formations, with minimum vibration, a highquality borehole, and maximum ROP. Predator Cutter Block Specifications Tool Series Reaming Cutter Count 5625 36 8000 50 10000 62 11625 93 14250 74 16000 48 16000 50 †

Backreaming Cutter Count 24 18 17 25 24 33 33

Cutter Size, mm

Rows

Cutter Type

Optimized Bit†

Opening Range, in

9 13 13 13 13 19 19

6 6 6 9 9 6 6

ONYX ONYX ONYX ONYX ONYX ONYX ONYX

MDi813 MSi716 MDi813 MDi813 MDi716 MDi816 MDi813

61⁄2–7 91⁄4–101⁄4 11–121⁄2 13–15 153⁄4–181⁄4 181⁄2–22 171⁄2–20

Optimized bit used in the final modeling with IDEAS, cutter block designs have been validated with other bit types.

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Cement Cleanout Blocks The Rhino XS reamer with cement cleanout blocks functions as a cleanout tool to remove the cement sheath that forms in the casing ID when drilling out the shoe track. The cement cleanout tool is typically run in tandem with a standard Rhino XS reamer.

Hevi-Wate drillpipe

Drill collar(s)

Benefits ■■

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Dependable cutter block retraction reduces risk of stuck BHAs 22-in, 16000 Rhino XS reamer with cement cleanout blocks

Acts as a stabilizer to drill new formation after the shoe track has been drilled out


Reliable hydraulic activation Cutter block design eliminates PDC cutter contact with casing ID

Because flow through the tool activates its cutter blocks, flow should be halted whenever the tool passes restrictions that are smaller than the tools diameter with its cutter blocks deployed. The tool is available in several sizes, and it can be configured for a wide range of casing IDs.

Cement cleanout block Drill collar(s)

22-in, 16000 Rhino XS reamer

8-in stabilizer Filter sub

MLWD

8-in stabilizer

MLWD

Rotary steerable system

181⁄8-in PDC bit

Example of BHA using Rhino XS reamer with cement cleanout blocks


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Rhino Stabilization System As well profiles and the individual components in modern drillstrings become more complex, reducing drillstring vibration becomes an increasingly important factor in building a quality borehole. The Rhino stabilization system is an integrated configuration consisting of the Rhino XS reamer and the Rhino stabilizer, which work in concert to reduce vibration downhole. The Rhino system’s concentric stabilizer increases lateral support in the enlarged wellbore and improves dynamic stability. This impedes vibration that can shorten the service life of downhole tools and surface equipment, slows drilling, results in an irregular borehole and—in severe cases—leads to loss of the entire BHA downhole.

Diamond-enhanced gauge inserts

The Rhino stabilizer is activated by the same ball-drop mechanism as the Rhino XS reamer and is typically run undergauge 30 ft above the reamer. Tungsten carbide and diamond-enhanced inserts in the stabilizer blocks ensure superior wear resistance.

Tungsten carbide hardfacing

Applications ■■

Drilling extended intervals with advanced RSS

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Extended-reach drilling

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Back reaming in loosely consolidated formations

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Drilling highly abrasive formations

Z-Drive tongue and groove actuation Rhino stabilizer

Benefits ■■

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Provides concentric, stable points of contact in the enlarged wellbore, increasing lateral support Helps ensure quality wellbores

Features ■■

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Tungsten carbide, diamond-enhanced inserts ensure superior wear resistance Cutters deployed with reliable Z-drive system

Rhino Stabilizer Specifications Tool Series Overall Body Diameter, in 4500 4.50 5625 5.62 6125 6.13 7300 7.25 8000 8.00 9250 9.25 10000 10.00 10375 10.38 11625 11.63 13000 13.50 14250 14.25 16000 16.375 16000 16.00

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Standard Fishing Neck Diameter, in 41⁄2 51⁄4 53⁄8 61⁄4 71⁄4 73⁄4 81⁄2 81⁄2 101⁄2 11 11 12 12

Enlarged Hole Size, in 43⁄4–53⁄4 61⁄2–7 7–71⁄2 8–9 9–101⁄4 101⁄4–113⁄4 11–121⁄2 113⁄4–131⁄2 13–15 141⁄2–161⁄2 153⁄4–181⁄4 171⁄2–20 181⁄2–22

Minimum Pilot Hole Size, in 43⁄4 57⁄8 63⁄8 71⁄2 81⁄4 91⁄2 101⁄2 103⁄4 121⁄8 131⁄2 143⁄4 161⁄2 171⁄2

Internal Bore Diameter, in 1.125 1.38 1.38 1.50 2.00 2.00 2.50 2.50 3.00 3.00 3.00 3.00 3.00

Maximum Thru Flow, gpm 230 350 350 350 750 750 1200 1200 1700 1700 1700 1700 1700


Fixed-Diameter Hole Openers The fixed-diameter hole opener enlarges boreholes using a range of milled tooth and tungsten-carbide insert (TCI) cutting structures that are available for a variety of formation conditions. The tool features three cleaning jets with replaceable nozzles, which continually clean the tool’s cutting structure, clearing debris buildup, and enabling sustained penetration. This is particularly important in sticky formations where balling can occur. The hole opener also enlarges holes in soft clays and shales, medium to hard shales, and limestones. The tool is available in 6¼– to 42–in size, with handtool detachable cutters for efficient redress and minimum downtime.

Applications ■■

Top-hole enlargement accommodates drive pipe, conductor casings, and large-diameter surface casings

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Hole enlargement at river crossings and other balling-prone formations

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Borehole enlargement in soft to hard formations


Cutting structures that are available for a variety of formation conditions Sealed bearings and TCI cutters in most diameters for increased application utility


Cutter arms can be changed on rig floor for quick replacement Three replaceable jets clean cutting surfaces, prevent balling, ensure fast penetration, and effective hole cleaning

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Upjets aid cuttings removal

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Robust design endures long interval drilling

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High-velocity oxy-fuel (HVOF) carbide coating reduces tool body erosion

Fixed-Diameter Hole Opener Specifications Tool Series Opening Diameter, in 17500 26000 32000 36000 42000

171⁄2 26 32 36 42


Minimum Pilot Hole Size, in 121⁄14 171⁄2 24 26 30

Fixed diameter hole openers with OD less than 26–in have 3 cutters (left) Fixed diameter hole openers with OD 26– to 36–in have 4 cutters (right) Fixed diameter hole openers with OD 42–in have 6 cutters (not shown)

Length, in

Body OD, in

Inner Bore Diameter, in

Number of cutters

693⁄4 851⁄2 11211⁄16 10211⁄16 11411⁄16

121⁄4 171⁄2 24 26 30

11⁄2 2 2 2 3

3 4 4 4 6

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Drilling-Type Underreamer The Drilling-Type Underreamer (DTU) is a tricone underreamer with cutter arms that deploy in response to hydraulic pressure on a pistoncam system. The underreamer runs in conjunction with a drill bit or a bullnose on a bottom-box connection depending on pilot hole condition or project objectives. The tool’s three-arm design can increase the pilot hole diameter up to 75%, depending on tool size. The underreamer’s cutters retract in the absence of hydraulic pressure and the closing force of a piston spring. This enables the tool to be repositioned for selective underreaming or retrieval from the well. The tool allows fluid flow to the bit or bullnose through the bottom connection; flow can be divided depending on the application. Orifice jets can be selected in accordance with existing hydraulics to cool cutters and maintain annular lift of cuttings.

Applications ■■

Wiping out bridges and keyseats

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Drilling and underreaming in fault zones and swelling formations

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Opening reservoir sections for gravel packing

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Underreaming while drilling (UWD)

Benefits ■■

Increases the pilot hole diameter up to 75%

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Can be selectively repositioned for selective underreaming or retrieval

Features ■■

API Reg box down for makeup to bit or jetted bullnose

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Milled-tooth, TCI, or PDC cutters available for formation demands

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Facilitates fluid passage to bits or jetted bullnoses to divert flow when necessary Cutter arms can be changed on rig floor for quick replacement

Drilling-Type Underreamer Specifications Tool Series Standard Optional Opening Opening Diameter, Diameter, in in 17000 32 24–32 22000 36 28–42 Bullnose Specifications Top Pin Connection, Reg 25⁄8 31⁄2 41⁄2 41⁄2 65⁄8 75⁄8 85⁄8

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Body Diameter, in

Collapsed Diameter, in

17 22

17 22

Body Diameter, in 35⁄8 43⁄4 61⁄4 71⁄2 8 9 10

Drilling-type underreamer

Fishing Neck Length, in 20 20

Fishing Neck Diameter, in 9, 10 9, 10

Overall Length, in 127 100

Top Pin/ Bottom Box Connection, Reg 75⁄8, 85⁄8 75⁄8, 85⁄8

Approximate Weight, lbm 3,800 4,400

Minimum Pilot Hole Diameter, in 171⁄2 24

Nominal Length, in 18 36 36 48 48 48 48


Reamaster-XTU Underreamer The Reamaster-XTU underreamer has two, large, robust cutter arms to facilitate greater cross-sectional cutting at the underreamer cutter pockets. Larger cutters also provide means larger sealed bearings and PDC cutters for optimized underreaming performance. The ability to run more drilling weight on the tool and spend more time on bottom, results in cost-effective underreaming. The Reamaster-XTU underreamer’s ability to increase an existing pilot hole up to 70% makes it ideal for a range of drilling and remedial operations. Milled tooth cutter

Fluid flow has been optimized using gun-drilled ports, which deliver more drilling mud to the underreamer and drillbit’s cutters. This improves hole cleaning efficiency and accommodates the fluid requirements of other downhole tools. The Reamaster-XTU underreamer has cutting structures that can be customized for a broad range of applications and formation types. The tool’s sealed-bearing milled-tooth and TCI cutters are designed specifically for underreaming operations with a capability that rivals the penetration rate and cutting structure life of a drill bit. PDC cutters are also available for long intervals.

TCI cutter

Applications ■■

Wellbore enlargement below restrictions

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Minimum clearance and expandable casing programs

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Underreaming while drilling (UWD)

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Gravel packs and expandable-screen completions

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Reaming out keyseats and clean up downhole ledges

Benefits

Reamaster-XTU underreamer

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Increase an existing pilot hole up to 70%

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Improves hole cleaning efficiency

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Accommodates the fluid requirements of other downhole tools

PDC cutter

Features ■■

Forged cutter arms endure high-shock and torque loads

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Sealed-bearing cutters extend on-bottom life

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Positive lock keeps arms deployed

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Optimized fluid distribution ensures drilling mud delivery

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Strategically placed nozzles ensures efficient hole cleaning

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Milled-tooth, TCI, and PDC cutting structures available for a range of formations

Reamaster-XTU Underreamer Specifications Tool Series Opening Diameter, in Pilot Hole Size, in 5750 7200 8250 9500 11750 16000

81⁄2, 9 11, 113⁄4, 121⁄4 97⁄8, 105⁄8, 11, 121⁄4, 131⁄2 121⁄4, 131⁄2, 15, 16 14, 15, 16, 171⁄2 20, 22, 24, 26


57⁄8–61⁄2 71⁄2–11 81⁄2–97⁄8 97⁄8–121⁄4 121⁄4–141⁄2 171⁄2–22

Collapsed Body Diameter, in

Fishing Neck Length, in

Fishing Neck Diameter, in

Overall Length, in

53⁄4 71⁄4 81⁄4 91⁄2 113⁄4 16

18 18 18 24 20 20

43⁄4 53⁄4 53⁄4 8 8 10

90 99 123 136 130 140

Top Pin/ Bottom Box Connection, Reg 31⁄2 41⁄2 41⁄2 65⁄8 65⁄8 85⁄8

Approximate Weight, lbm 500 700 900 1,100 1,700 3,200

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Rock-Type Underreamer The Rock-Type Underreamer (RTU) features three specially designed cutter arms with large cones. When deployed, these arms enable the tool to underream boreholes to nearly twice their original diameter. The hydraulically operated cutting arms lock into the open position when fluid pressure is applied, and automatically retract into the body when pressure is relieved. The RTU underreamer features a range of milled-tooth and TCI cutting structures and can be easily tailored to specific formation conditions. To meet budget variables, milled-tooth cutters are available in openand sealed-bearing configurations. PDC cutters are also available on request.

SDS

DG, C4

DT

V2

Applications ■■

Underreaming hard formations with no bit or bullnose below the underreamer

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Underreaming for openhole gravel pack completions

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Special casing programs in heaving shales or fault zones

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Opening sections for sidetracking

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Underreaming solely to create a pilot hole

Benefits ■■

Can be easily tailored to specific formation conditions

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Range of cutters meets budget variations

Features ■■

Wide selection of cone and cutter types to ream in a variety of formations

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Three-cone design accommodates relatively large cones

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Orifice jets control mud volume to meet downhole conditions

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Cutter arms can be changed on rig floor for quick replacement

Rock-Type Underreamer Specifications Tool Standard Opening Optional Series Diameter, in Opening Diameter, in 6–9 4500 61⁄2, 81⁄2 5700 81⁄2, 9, 93⁄4, 10, 101⁄2, 11 8–11 11–12 6000 105⁄8–13 7200 91⁄2–14 9–14 8200 10–16 10–16 9500 121⁄4–171⁄2 121⁄4–18 11700 15–22 143⁄4–22 15000 LP 26 171⁄2–30

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Body Diameter, in

Collapsed Diameter, in

41⁄2 53⁄4 61⁄8 71⁄4 81⁄4 91⁄2 113⁄4 143⁄4

45⁄8 6 61⁄8 73⁄8 83⁄8 93⁄4 121⁄4 143⁄4

Rock-type underreamer

Fishing Neck Length, in 18 18 18 18 18 18 20 20

Fishing Neck Diameter, in 41⁄8 43⁄4 43⁄4 53⁄4 53⁄4, 8 8 8 8, 9

Overall Length, in 67 761⁄2 781⁄2 86 89 91 91 97

TCI

Top Pin/ Bottom Box Connection, Reg 27⁄8 31⁄2 31⁄2 41⁄2 41⁄2, 65⁄8 65⁄8 65⁄8 65⁄8, 77⁄8

Approximate Weight, lbm 235 380 380 775 920 1,160 1,670 2,800

Minimum Pilot Hole Diameter, in 43⁄4 6 61⁄2 75⁄8 81⁄2 97⁄8 121⁄4 171⁄2



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