Bits Catalog

5/21/2018 Bits Catalog

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2012 Product Catalog


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Headquarters1310 Rankin Rd.

Houston, TX 77073-4802

www.slb.com

Copyright 2011 Schlumberger. All rights reserved.

No part of this book may be reproduced, stored in a

retrieval system, or transcribed in any form or by any means

electronic or mechanical, including photocopying and

recording without the prior written permission of the

publisher. While the information presented herein is

believed to be accurate, it is provided as is without

express or implied warranty.

Specifications are current at the time of printing.

11-BT-0027

An asterisk (*) is used throughout this document to denote

a mark of Schlumberger. Other company, products and

service names are the properties of their respective owners.


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Table of Contents

Technological Expertise 1 17

Innovative Smith Bits technology for every stage of drilling

Fixed Cutter Bits 19 33

A wide range of PDC and diamond-impregnated bits

Roller Cone Bits 35 50

A comprehensive selection for various applications

Percussion Hammers and Bits 53 56

Impax hammer products designed for oilfield applications

Borehole Enlargement 59 71

An extensive catalog of robust and reliable tools

Reference Guide 73 93


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1

Technological Expertise


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2

Engineering and Modeling

- IDEAS* Integrated Drillbit Design Platform

- Computational Fluid Dynamics (CFD) Analysis

- i-DRILL* Engineered Drilling System Design

- Advanced Services Engineering (ASE)

- DBOS* Drillbit Optimization System

- YieldPoint RT* Drilling-Hydraulics and Hole-Cleaning Simulation Program

- DRS* Drilling Record System

PDC Technology

- ONYX II* Premium PDC Cutters

Roller Cone Technology

- Hydraulics

- Inserts

Diamond-Impregnation Technology

- Grit Hot-Pressed Inserts (GHIs)

Technological Expertise

Innovative Smith Bits technology provides analyses, optimization, and support for every stage ofthe drilling program, from planning to execution


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The IDEAS* platform uses advanced simula-

tion and modeling to design and certify every

new Smith Bits drill bit. It has five basic ele-

ments that enable it to optimize bit perfor-

mance.

Comprehensive drilling systemanalysisThe design process takes into account the

effects of the lithology at the rock-cutter

interface, the drillstring, the drive system,

individual BHA components, and the total

system on bit behavior in a dynamic drilling

environment. It also takes into account the

specific operating parameters and the inter-

action between individual elements of the

drilling assembly.

Engineering and ModelingIDEAS Integrated Drillbit Design Platform

Delivering application-specific drill bits with higher performance and greater reliability

Holistic design processSmith Bits design engineers account for

every critical variable. Virtually every cone

or cutter position is selected to create a

stable bit that rotates around its center, a

key requirement for efficient drilling.

Application-specific enhance-

mentsContinuous improvement results in bits for aspecific application that consistently out-

perform previous designs when measured

against the same parameters, for example,

ROP, durability, and specific bit behavior

with a rotary steerable system. Drill bits that

are certified by the IDEAS platform are

dynamically stable within the operating

envelope for which they are designed,

leading to longer bit runs and less stress on

the BHA.

Each certified bit undergoes rigorousdesign evaluation and testing to produce a

detailed application analysis of how it will

perform for a specific drilling program.

Rapid solutions with reliableresultsBy using sophisticated modeling tools and

by accounting for a multitude of dynamic

variables in a virtual environment, the

IDEAS platform moves bits through the

design process much quicker, while

ensuring better reliability and performance

than ever before. The traditional trial-and-

error approach is replaced by laboratory

tests and simulations to quantify variables

such as cutter forces and rock removal

rates.

Integration of advanced materialsStronger and more durable advanced

cutter materials are used more effectively

by working in conjunction with IDEAS

design and simulation capabilities. The

resulting bit has abrasion- and impact-

resistant cutters, and an optimal design for

high performance.

IDEAS platform eliminates the costly and time-consuming trial-and-error methods of the tradi-tional drillbit design process, enabling Smith Bits todeliver a better solution faster.

Define

Performance

Objectives IDEAS SimulationDesignTestAnalyze

Build Bit

Test Bit

Certify Bit

Integratenew bit intoproduct line

The IDEAS Platform

www.slb.com/IDEAS


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Extensive analyses of drill bits designed for

directional applications using the IDEAS*

integrated drillbit design platform shows that

a single design can provide exceptional

performance with a variety of directional

drilling systems, if it is dynamically stable.

Often, the range of special features incorpo-

rated into conventional directional bits

merely allows an intrinsically unstable bit

design to drill acceptably for a specific appli-

cation. If the bit is subsequently used with a

slightly different BHA or in a different appli-

cation, it becomes unstable and a new or

significantly modified bit is required.

Bits for directional drilling that have IDEAS

certification remain stable and provide supe-

rior performance with different types of

steering systems in a wide range of applica-

tions. Changing the system configuration or

operating parameters does not diminish the

performance of the bit. Drilling with a stablebit reduces costs and equipment failures in

addition to providing a smooth, high-quality

wellbore.

Engineering and ModelingIDEAS Certification for Directional Applications

Improving performance, reduces risk, and keeps directional wells and drilling budgets on target

www.slb.com/IDEAS


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Efficient hydraulics for improved performance and lower drilling costs

Smith Bits design engineers use CFD to

model the interaction of drilling fluids with

the bit and the wellbore. Complex algorithms

enable the simulation of a wide variety of

downhole conditions, allowing engineers to

evaluate various blade and nozzle configura-

tions in order to optimize flow patterns for

cuttings removal. Ensuring the cutting struc-

ture is always drilling virgin formation

improves bit performance. Extensive use is

made of this sophisticated technique to

maximize the available hydraulic energy,

providing bits that will drill at the lowest

possible cost per foot.

Using CFD to visualize flow patterns enables designers to analyze the effects of design modifications on bitperformance and choose the optimum solution.

Engineering and ModelingComputational Fluid Dynamics (CFD) Analysis


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i-DRILL* engineered drilling system design

uses predictive modeling to identify solu-

tions that minimize vibrations and stick/slip

during drilling operations, and optimize BHA

performance for a given environment.

Specially trained engineers simulate the

behavior of the bit, as well as each compo-

nent of the BHA and the drillstring. They

evaluate a range of options to reduce

harmful vibrations, thus increasing equip-

ment life, minimizing failures, increasing

ROP, improving hole condition and direc-

tional control, and decreasing overall drilling

cost. Various combinations of drillbit options,

drilling assembly components, drillstring

designs, surface parameters, component

placement, and overbalance pressures can

be examined for the specific lithology.

Advanced graphics capabilities illustrate the

results with clarity.

Reliable simulation of downholebehavior eliminates trial-and-errorEmploying the IDEAS* integrated drillbit

design platform, i-DRILL drilling system

design quantifies the vibrations and ROP for

a given drilling system as a function of time.

This is accomplished by combining a bit

rock cutting model based on extensive labo-

ratory testing with a finite element analysis

of the bit and drillstring.

Analyzing the dynamics of the drilling

assembly through multiple formations of

variable compressive strength, dip angle,homogeneity, and anisotropy is feasible, a

critical factor in obtaining optimal perfor-

mance through formation transitions. Virtual

testing of new technology and unconven-

tional approaches eliminates the risk and

expense of trial-and-error on the rig.

Integration of data from diversesources improves accuracyUsing offset well data, surface and down-

hole measurements, and a thorough knowl-

edge of products and applications, the

Engineering and Modelingi-DRILL Engineered Drilling System Design

www.slb.com/idrill

i-DRILL design process creates a virtual

drilling environment. Detailed geometric

input parameters and rock mechanics data

are also taken into account. Simulating the

drilling operation enables evaluation of the

root causes of inefficient and damaging BHA

behavior.

i-DRILL design capabilities Identify the true technical limit of perfor-

mance without risking lost rig time associ-

ated with exceeding the limit or inefficien-

cies resulting from operating too far below

the limit.

Eliminate unnecessary trips to change

BHAs when trying to identify the optimum

drilling system .

Predict the performance of new drillbit

designs.

Predict the dynamic behavior of direc-

tional BHAs in space and time.

Identify weak areas in the drillstring andBHA to help prevent the loss of tools

downhole.

Minimize harmful lateral, torsional, and

axial vibrations; and stick/slip, through the

selection of dynamically stable drilling

assemblies.

Balance drillbit and underreamer cutting

structure loading to maximize dual-diam-

eter BHA stability.

Develop improved drilling program sched-

ules with reduced risk of unplanned

delays.

i-DRILL analysesThe following analyses are available:

drilling system check to evaluate dynamic

behavior; identify issues with vibration,

bending moments, and torque; and select

the optimal system

bit analysis to identify the design that will

yield the highest ROP under stable condi-

tions

bit durability and ROP through different

formations.

bit-underreamer balance to determine the

combination that will result in the highest

ROP under stable conditions

BHA comparison to investigate directional

behavior while minimizing vibrations

range of weight on bit (WOB) and drillbit

revolutions per minute (rpm) for maximum

ROP under stable conditions

postwell follow-up to determine usage and

effectiveness of prewell i-DRILL design

recommendations

Maximize performance with a dynamically stable drilling assembly.


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The ASE team has an established track

record of lowering drilling costs through

improved performance, by recommending

the ideal bit for the applicationa vital

aspect of a comprehensive well plan. Bit

recommendations and operational advice

are based upon the technologies and oper-

ating parameters best suited for a particular

application.

Expert drillbit selectionThe ASE group provides an experienced bit

application specialist for the clients drilling

team, to deliver engineered bit recommen-

dations and advice to both the operator and

the

service providers on the day-to-day require-

ments for maaintaining superior bit perfor-

mance. ASE engineers consider the entire

drilling environment, including the formation,

the components of the BHA, drilling fluids,

rig capabilities, rig crew, and any specialdrilling objectives in their search for the

optimum bit and subsequent maintenance of

its efficiency throughout its life.

The engineer uses several proprietary tools,

such as the

DRS* drilling record system, which

includes detailed bit runs from oil, gas,

and geothermal wells around the world

DBOS* drillbit optimization system, which

helps determine the appropriate combina-

tion of cutting structure, gauge protection,

hydraulic configuration, and other bit opti-mizing features

YieldPoint RT* drilling-hydraulics and

hole-cleaning simulation program for jet

nozzle optimization.

Optimized drilling planThe DBOS program uses knowledge gained

from an analysis of offset wells from the DRS

system and a spectrum of other relevant

information. It provides a thorough recon-

struction of expected lithologies (gleaned

from well logs from the closest offset wells),

Engineering and ModelingAdvanced Services Engineering (ASE)

In-house bit recommendations and operational advice

www.slb.com/ase

a formation analysis, rock strength analysis,

and both roller cone and fixed cutter bit

selections.

The YieldPoint RT program creates a graph-

ical user interface to aid drilling engineers in

specifying mud types and properties that

satisfy rheological models of drillstrings and

well annuli. The software can answer ques-

tions about hole cleaning, with data from the

formations to be encountered. Using a

cuttings transport model, the program can

help assess potential hole-cleaning difficul-

ties during the well planning stage, thus

minimizing problems during actual drilling

operations.

Operational needs and the well plan are also

taken into consideration, including casing

points and hole sizes, well directional plot,

and expected formation tops. The result is

an optimized minimum cost per foot

program, often with multiple options and

alternatives.

Continuous evaluation whiledrillingTo establish measurable goals, the ASE engi-

neer prepares a comprehensive plan. During

drilling, performance is evaluated continu-

ously against this plan. Upon completion of

the well, a postwell analysis measures the

success of the plan and provides a perma-

nent formal reference for future wells.

The appropriate rig and office personnel are

briefed on the drilling program and monitor

the well prognosis during implementation of

the well plan. Unexpected performance or

events that arise are identified and investi-

gated, and decisions are made to correct the

issues, subject to the objective of main-

taining peak drilling efficiency and safety.


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Post Well AnalysisA thorough performance assessment is conducted upon completion

of the well evaluating every part of the drilling operation. The ASE

engineer, as part of the drilling team, makes recommendations for

improvements related to bit selection and drilling for future well

plans.

The ASE team provides value by recommending the best bit for the

specific application, which will deliver the most efficient and

economical drilling performance.

Engineering and ModelingAdvanced Services Engineering (ASE)

www.slb.com/ase


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Engineering and ModelingDBOS Drillbit Optimization System

To achieve the minimum cost per foot with a higher degree of

certainty and reduced risk, the DBOS* Drillbit Optimization System

identifies the best drill bit for the interval to be drilled. This software

based system uses offset well data to choose a fixed cutter, roller

cone, or turbodrill drill bit that has the appropriate combination of

cutting structure, gauge protection, hydraulic configuration, and

other critical characteristics. Since its inception, the DBOS system

has provided significant cost and time savings for operators around

the world, while creating a supporting database of more than 20,000

wells. The system incorporates a thorough analysis of offset well

data including well logs, formation tops, mud logs, core analysis,

rock mechanics, drilling parameters, drillbit records, and dull bit

conditions.

DBOS comprises

a petrophysical log analysis program

proprietary algorithms for rock compressive strengths, drillbit

performance analysis, and drillbit selection

well log correlation and statistic analysis software

a geologic mapping program

The flexibility of the system allows engineers to analyze various

levels of information and deliver a bit strategy based on input from a

single offset well, a multiwell cross section, or a full-field mapping

and regional trend analyses.

www.slb.com/dbos

DBOS evaluation process1. Evaluation of expected formation types and their section lengths

from offset logs.

2. Determination of unconfined compressive strength, effective

porosity, abrasion characteristics, and impact potential.

3. Identification of one or more potentially optimal bit types and

various applicable features.

4. Prediction of the cost per foot for each bit and configuration.

5. Drillbit selection for planned hole (simulation).

Operator deliverables

Various levels of analysis are offered, and for each level, data ispresented graphically in log plot form, and statistically in the interval

analysis plots. The analysis evaluates key bit performance variables

over the given intervals, identifying which bit will be the most

successful for drilling through specific single intervals or over

multiple intervals, based on experience data and the knowledge

based heuristics.

Parallel analysis for roller cone bit options, PDC bit applications and

high-speed turbodrilling options are all considered. The final

proposed bit program combines this input for optimized Interval cost

per foot.


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Engineering and ModelingDBOS Drillbit Optimization System

Input parameters include:

drillbit record information

directional surveys

real-time ROP and mud log data

wireline or LWD formation evaluation data

rock type and strength data

hydraulic and mechanical energy factors.

Neural networks, planned run simulation and real-timeoptimizationNeural networks have been used in DBOS for synthetic log genera-

tion since 1997, and serves as the principal modeling for

DBOS OnTime* real- time drilling optimization system. Artificial

neural networks (ANNs) have proven accuracy generating synthetic

logs (used primarily for sonic log generation) with R^2 (goodness of

fit) values in the high 90 percentiles, compared to traditional offset

www.slb.com/dbos

correlation methods. Neural networks provide system response

characteristics, very valuable in non-linear multi-input solution.

Drillbit performance can be predicted prior to drilling (ROP, Dull) in

run simulation. In pre-drilling simulation, drilling systems can be

tested in advance to find the most efficient way to drill.

Real-time applicationsOptimized drilling parameters can be assessed and delivered to the

driller and rig floor in realtime, giving predictions ahead of the bit.

The results can be monitored with respect to improved ROP, longer

drillbit life, or reduced downhole shock and vibration. DBOS has

contributed to improvements in bit run performance on the order of

20-40% or better in ROP, longer bit life, reduced incidents of drillbit

related failures.


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Engineering and ModelingYieldPoint RT Hydraulics and Hole-Cleaning Simulation Program

Optimized hole-cleaning solutions

The YieldPoint RT* program identifies potential problems with hole

cleaning in the planning stage, rather than during drilling operations

when they can have a significant impact on the cost of the well. It

aids drilling engineers in specifying mud type and properties to

satisfy rheological models of drillstrings and well annuli.

This comprehensive program uses sophisticated algorithms to

deliver solutions for conventional jet nozzle optimization and

selection. It creates simulations of mud properties, flow rate, ROP,

and total flow area. The virtual model then demonstrates the effects

on observed bit hydraulic factors and on hole cleaning.

Diverse inputs for real-time assessmentYieldPoint RT program allows data to be input and retrieved via an

Internet connection and the Web-based wellsite information transfer

standard markup language (WITSML), by authorized wellsite

providers and off-location users such as

the well operator

drilling contractors

mud loggers

rig instrumentation and wireline companies

drilling fluid service companies casing running service providers

directional drillers

drilling and exploration engineers and managers

reservoir engineers

management personnel

seismic survey companies

process optimization consultants

materials suppliers.

Wellsite service providers can contribute expertise to the common

store via the WITSML interface, and then query the data store for

combined information from other wellsite services. This information

can support program analysis, visualization, and potential correctiveactions, decision making in drilling and production operations in real

time. Hydraulics can be optimized to maximize efficiency as the well

is being drilled.

Operating company personnel can compile information from any mix

of vendors, view and monitor current wells via Web-based

applications, and extract reports at any time. The result is a real-time

solution that yields substantial cost savings.

www.slb.com/yieldpointRT


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Engineering and ModelingDRS Drilling Record System

An extensive library of bit run information

The Smith Bits DRS* drilling record system is

a collection of nearly 3 million bit runs from

virtually every oil and gas field in the world.

The database was initiated in May 1985 and

since that time, records have been continu-

ously added for oil, gas, and geothermal

wells. With this detailed data and the capa-

bilities of the IDEAS* integrated drillbit

design platform, Smith Bits engineers can

simulate bit performance and make changes

to their bit designs to optimize performance

in a specific application.

In addition, the system enables the DBOS*

drillbit optimization system to ensure that the

right bit is run in a given formation. With this

plan in place prior to drilling the well,

customers are able to reduce risk, lower

drilling costs, and shorten the total time

required to drill their wells.

The inclusion of bit record data from the

client wells in the DRS system contributes to

better drillbit selection and application for

your drilling program. The system can be

accessed through Smith Bits applications

engineers or sales representatives.

www.slb.com/records


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PDC TechnologyONYX II Premium PDC Cutters

www.slb.com/onyxII

ONYX II cutters have established a new benchmark for performance in thetoughest drilling applications

New technology increasesperformanceWhen the ONYX* PDC cutter was introduced

its resistance to abrasive wear and thermal

degradation significantly increased PDC bit

performance in hard and abrasive formations.

Pushing the limits of PDC bit performance

still further would mean creating an entirely

new cutter technology. After extensive dull bit

analysis and the introduction of new materials

and manufacturing processes, Smith Bits

launched the ONYX II* premium PDC cutter:

Capable of retaining its sharp edge longer

than previous cutters, the new ONYX II

enables PDCs to drill even more efficiently in

the harshest conditions, which has signifi-

cantly improved overall PDC bit performance

while reducing drilling costs.

Comprehensive laboratoryevaluationA continued investment in the most advanced

component testing facilities by Schlumbergerhas resulted in an improved understanding

of the fundamental cutter/rock interaction.

Using specialized laboratory equipment, our

research and development engineers evalu-

ated the new generation ONYX II cutter to

measure it against the original ONYX shearing

element. In a controlled laboratory compar-

ison, ONYX II cut 20% more footage and

maintained a significantly better dull condi-

tion when compared to the original ONYX

cutter. These results clearly indicate improved

thermal stability enables ONYX II to maintain

its structural integrity and resist diamond

spalling and chipping.

Cutter technology hasevolved over the yearsto enhance the perfor-mance of PDC bits. Wearcharacteristics have beenevaluated in controlledlaboratory simulationson granite, and ONYXII shows significantlyimproved resistance toabrasion, as measuredagainst previous gen-erations of PDC cutters.(above cutters shown afterstandard granite abrasiontest)

ResistancetoAbrasion

ONYX

2009

ONYX II

2011Second generation

premium PDC cutters

2006

First generation

premium PDC cutters

2003

Extended granite abrasion test

ONYX ONYX II


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Roller Cone TechnologyAdaptive Hydraulics System

Because of the wide range of drilling appli-

cations for roller cone bits, no single hydrau-

lics configuration is optimal for every situa-

tion. Different applications require each of

the three primary functions of bit hydrau-

licscutting-structure cleaning, bottomhole

cleaning, and cuttings evacuationto

varying degrees. With the Flex-Flo* adaptive

hydraulics system, Smith Bits offers the ideal

configuration for each application

Very soft and/or

sticky formationsthat generate verylarge volumes of

cuttings with MilledTooth bits and very

soft TCI bits.

Zone 1Low strength

formations thatgenerate large

cuttings volumesand drill with soft

TCI bits.

Zone 2

Medium strengthformations that

generate moderatecuttings volumeswith mediumhard

TCI bits.

Zone 3

High strengthformations thatgenerate low

cuttings volumeswith hard TCI bits.

Zone 4

Soft/StickyHard/Abrasive

Cutting Structure Cleaning

Bottom-Hole Cleaning

Cuttings Evacuation

Hydraulic Function vs. Formation

H

ydraulicFunction

Need

V-Flo

V-Flo* vectored-flow

nozzle configuration uses

three directed nozzles to

allocate available

hydraulic energy for

improved penetration

rates through superior

cutting-structure cleaning

and efficient cuttings

evacuation.

X-Flo

The many variations of

X-Flo* crossflow nozzle

configuration allocate

available hydraulic energy

to improve penetration

rates through cone

cleaning and dramatically

increased impingement

pressure, needed for

superior bottomholecleaning.

S-Flo

In applications with high

percentages of solids in

the mud and in abrasive

formations, S-Flo* stan-

dard-flow nozzle configu-

ration uses three identical

nozzles to allocate

hydraulic energy for

increased bit life.

To help select the most suitable bit hydrau-

lics system, typical applications have been

divided into four categories or zones deter-

mined by formation types, ranging from very

soft to very hard. Within each zone, the rela-

tive importance of the three hydraulics

system functions can be seen on the graph.

Bit hydraulics performance can be enhanced

by using this guide to select an appropriate

system, which can then be refined for

specific applications by consulting aSmith Bits representative.


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Roller Cone TechnologyTyphoon Hydraulics

Smith Bits engineers use sophisticated

computational fluid dynamics (CFD) analysis

to ensure optimum flow for cuttings removal,

so that the cutting structure is always drilling

virgin formation. Typhoon* hydraulics is a

feature offered for roller cone bits with a

diameter of 16 in and larger, that uses both

vectored extended (VE) nozzles and dome jet

(J3) nozzles.

Shamal* carbonate-optimized TCI drill bits withTyphoon hydraulics incorporate three vectoredextended (VE) nozzles and three dome jet (J3) innernozzles to apply maximum hydraulic energy to thebottom of the wellbore, enhancing cuttings removaland increasing ROP.

CFD analysis allows Smith Bits engineers to opti-mize available hydraulic energy for maximium ROP.

Superior Hole Cleaning for Large OD Boreholes

www.slb.com/shamal

VE nozzles direct the fluid flow with preci-

sion to the leading edge of the cones, while

the J3 nozzles direct flow towards the inter-

mesh area between the cones. The

combined effect of these six, precisely

oriented nozzles is a flow pattern that signifi-

cantly improves cone cleaning, optimizes the

displacement of cuttings from the bottom of

the hole up the drillstring, and maximizes

ROP.


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Insert OptionsA large selection of insert geometries and material options, diamond

or tungsten carbide, help to optimize bit characteristics for specific

applications. A key focus of the Smith Bits R&D program, enhance-

ments to inserts are constantly being incorporated into new and

existing bit designs.

Geometry Choices

Smith Bits pioneered the use of specific insert shapes in 1995, anduses proprietary tools to determine the best geometry for a given bit

design. Available options include the following:

Conical and chisel inserts are designed for hard and soft forma-

tions respectively.

The unique geometry of the DogBone* durable and aggressive

drillbit insert is designed for maximum ROP and impact resistance.

The asymmetric conic edge (ACE) insert is a hybrid of the conical

and chisel inserts. It has an offset conical top for increased

strength, and a flatter leading side to enhance scraping. The

design is highly resistant to breakage and impact damage, yet

more aggressive and effective in softer formations than a standard

conical insert. Incisor* concave drillbit insert combines the benefits of the ACE,

chisel, and DogBone designs. With a sharp offset, C-shaped crest

and larger corner radii, it is designed for soft to medium-hard

formations.

Material ChoicesInsert material grades are not specific to a particular design. Mate-

rials can be optimized for individual applications to maximize perfor-

mance, reliability, and durability.

Smith Bits was the first company to offer diamond-enhanced inserts

(DEI) in roller cone bits, and remains the performance leader in this

technology, which helps ensure maximum durability in the most chal-

lenging applications. Diamond inserts can be used in the heel row,

the gauge row, and on the bit leg.

Incisor DogBone ACE Relieved Gauge Chisel Conical

Chisel

Coarse Carbide Microstructure

Diamond-Enhanced Insert

Roller Cone TechnologyInserts


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Diamond-ImpregnationGrit Hot-Pressed Inserts (GHI) Technology

GHIs are individual cylinders of impregnated material used in

Kinetic* diamond-impregnated bits. Each insert is manufactured

using a proprietary granulation process that ensures a much more

uniform distribution of the diamond material than the conventional

pelletization process. The result is a more consistent GHI, which is

significantly more durable, maintains its shape, and drills faster for a

longer period of time.

Individual GHIs are similar to small grinding wheels, so the depth of

cut with each rotation of the bit is very small. While drilling, GHIs

continuously sharpen themselves by grinding away the bonding

material to expose new diamonds. Smith Bits GHIs are customized

with different bonding materials and diamonds to match the forma-

tion being drilled and the drive mechanism used. Because the GHIs

are raised and allow a greater flow volume across the bit face, they

enable Kinetic bits to drill faster in a wider range of formations.

Uniform diamond distribution and optimized mate-rial wear rates.

Smith Bits GHIs are more durable than conven-tional GHIs, and will drill faster for a longer periodof time.


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Fixed Cutter Products


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Directional PDC Drill BitMatrix or steel drill bits for improved directional response

SHARC* High-Abrasion-Resistance PDC Drill BitMatrix or steel bits for improved durability and wear resistance

Spear* Shale-Optimized Steel-Body PDC Drill Bit

Steel body PDC drill bits for improved performance in shales

Standard PDC Drill Bit Premium performance with excellent durability

Kinetic Drill Bits Matrix bits for high rotary speed applications including positive

displacement motors (PDMs) and turbodrilling

Fixed Cutter Bits Product Line


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IDEAS* integrated drillbit design platform

and field experience have shown that a

single bit design can provide exceptional

performance with a variety of directional

drilling systems, if it is dynamically stable.

The earlier perception was that each type of

rotary steerable system (RSS) or steerable

motor BHA required its own bit design with

highly specialized directional features.

Directional bits with IDEAS certification are

stable and produce less torque and stick/slip

in transitional drilling. The risk of time-

consuming and costly trips due to vibration

and shocks is greatly reduced.

IDEAS certification for directional bits ensures excellent steering response and improvedperformance

M Di 6 1 6Cutter SizeBlade Counti - IDEAS Certified

D - IDEAS Directional Certified

M/S - Matrix or Steel

DirectionalNomenclature

Type Size Availability, in

SDi613 17 1/2

SDi616 13 1/2

MDi416 6 1/8

MDi513 5 5/8, 6 1/8, 6 1/4, 7 7/8, 8 3/4

MDi516 6 1 /8, 8 1/2

MDi519 8 3/4, 14

MDi613 6 3/4, 8 5/8, 8 1/2, 9 1/2, 9 7/8MDi616 8 1/2, 14 3/4

MDi619 12 1/4, 14 1/2, 16, 17 1/2

MDi713 5 7/8

MDi716 8 1/2, 12 1/4, 14 3/4

MDi719 8 1/2, 10 5/8, 12 1/4, 14 1/2

MDi813 5 3/4, 8 3/4, 12 1/4, 14 1/2,

14 3/4, 16 1/2

MDi816 8 3/8, 8 1/2, 10 5/8, 12 1/4,

13 3/4, 17 1/2, 18 1/8, 18 1/4


SD519 16, 17 1/4

MD519 8 1/2, 12 1/4

MD611 5 7/8

MD613 6, 6 1/8

MD616 6, 8 3/8, 9 7/8, 12 1/4, 14 3/4

MD619 8 1/2, 9 1/2, 12 1/4, 17

MD813 8 1/2MD816 6, 6 1/8, 8 1/2, 9 1/2, 12 1/4,

16 1/2

MD819 12 1/4

MD913 8 1/2, 12 1/4

MD916 8 1/2, 12 1/4

MD919 12 1/4, 13 1/2

Fixed Cutter BitsDirectional PDC Drill Bit

www.slb.com/directional


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MDSi613 5 7/8, 6, 6 1/8, 6 3/4, 7 7/8, 8 3/4

MDSi616 7 7/8, 8 1/2, 8 3/4, 9 7/8, 12, 12 1/2, 16, 17 1/2

MDSi716 7 7/8, 8 1/2, 8 3/4, 9 7/8, 12, 12 1/2, 16, 17 1/2

MDSi619 14 3/4, 16

MSi416 6 1/8, 6 3/4, 7 7/8, 8 1/2, 8 3/4

MSi513 6 1/8, 6 1/4, 7 7/8

MSi516 6 1/8, 6 3/4, 7 7/8, 8 1/2, 8 3/4, 9 7/8, 12MSi519 7 7/8, 8 1/2, 8 3/4, 9 7/8, 12 1/4

SDSi519 12 1/4, 17 1/2

MSi611 6 1/8

MSi613 6, 6 1/8, 6 1/4, 6 1/2, 6 3/4, 7 7/8, 8 1/2, 8 3/4, 12

MSi616 6, 6 1/8, 6 1/2, 6 3/4, 7 7/8, 8 1/4, 8 1/2, 8 3/4, 9 1/2, 9 7/8,

10 5/8, 12 1/4, 14 3/4, 16

MSi711 5 5/8, 5 7/8, 6

MSi716 7 7/8, 8 1/2, 8 3/4, 9 7/8, 12, 12 1/2, 16, 17 1/2

MSi816 7 7/8, 8 3/8, 8 1/2, 8 3/4, 9 7/8, 12 1/4, 16, 17 1/2

MSi1013 12

Fixed Cutter BitsSHARC High-Abrasion-Resistance PDC Drill Bit

M D Si 6 1 9Cutter SizeBlade Counti - IDEAS Certified

S - SHARC



SHARCNomenclature

The cutting-structure layout of a SHARC* PDC drill bit features two

rows of cutters set on certain blades. Each row reinforces the other

to provide maximum durability over the critical nose and shoulder

areas of the bit, ensuring that ROP capability is not compromised.

Additionally, the double rows are oriented to ensure that hydraulic

cleaning and cooling efficiency are maintained. This feature is

important not only in abrasive interbedded sands, but also in surface

intervals with high ROP or when hydraulic energy is compromised,

for example, on motor runs.

When drilling hard, highly abrasive formations, SHARC PDC bits

maintain maximum ROP over the target interval. Drilling faster and

staying downhole longer, these bits are achieving superior perfor-

mance in challenging applications all over the world.

The key to achieving both bit durability and maximum ROP is main-

taining drillbit stability across a broad range of downhole conditions.

SHARC bits are designed using the IDEAS* integrated drillbit design

platform, specifically to eliminate vibration, resulting in maximum

stability for superior wear resistance. Their durability eliminates

unnecessary trips, saving time and costs for the operator.

Bit durability and maximum ROP in abrasive formations

www.slb.com/sharc


27/100

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SDi513 6, 6 1/8, 6 1/4, 6 1/2, 6 3/4, 7 7/8, 8 1/2, 8 3/4

SDi611 6 3/4, 8 3/4

SDi613 8 1/2, 8 3/4

SDi711 6 1/8, 6 1/2, 6 3/4

SDi713 6 1/8, 6 3/4, 7 7/8, 8 1/2, 8 3/4

Fixed Cutter BitsSpear Shale-Optimized Steel-Body PDC Drill Bit

Spear PDC drill bits have been specifically designed to improve the economics of shale plays

Spear* shale-optimized drill bits efficiently drill a curve as well as a

long lateral hole section, minimize bit balling and short runs, improve

ROP, and enhance directional control. Conventional PDC bit designs

target either the curve or the lateral section, but not both.

Efficient cuttings removalSpear drill bits minimize buildup of cuttings in front of the bit and

improve ROP with the following engineered features:

Directional mud flow cleans debris so that a sharp cutter edge

always meets rock, maximizing ROP.

Bullet-shaped body streamlines the bit, making it easier for

cuttings to sweep around the body and into the junk slot.

Reduced body diameter increases the distance between the

borehole and the bit body in the junk slot, improving the ability of

cuttings to pass through the slots. Greater area around the body

allows the bit to pass over or through a cuttings bed, without blade

packing and nozzle plugging.

Greater blade height increases the junk slot area.

S D i 6 1 3

Cutter SizeBlade Count

i - IDEAS Certified


Spear Shale-Optimized Steel-Body

SpearNomenclature

www.slb.com/spear

Spear bits feature a bullet-shaped body profile

that makes it easier for cuttings to sweep around

the body and into the junk slot


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Fixed Cutter BitsStandard PDC Matrix and Steel Bits

M i 6 1 6Cutter Size

Blade Count

i - IDEAS Certified


Standard PDCNomenclature

Features such as cutter types, cutter layout,

and blade geometry are continuously being

evaluated and improved to deliver value and

drive down drilling costs. Certification with

IDEAS* integrated drillbit design platform

ensures these bits offer optimum

performance.

The workhorse of the oilfield,delivering premiumperformance with superiordurability.

8 1/2-in Mi616


Mi413

Mi416

Mi419

Mi513

Mi516

Mi519

Mi613

Mi616

Mi619

Mi713

Mi716

Mi811

Mi813

Mi816

Mi913

Mi916

Mi919

Mi1016

S416

S422

S516

S519

S522

S613

S616

6 1/2

6 1/8, 6 1/4, 6 3/4, 7 5/8, 7 7/8

6 1/8, 8 1/2, 9 7/8

6 1/4, 6 1/2, 7 7/8, 8 3/4

6 1/2, 8 3/4, 12 1/4

8 3/4, 9 7/8, 12-1/4

6 1/2, 7 7/8, 8 3/4

7 7/8, 9 7/8, 12 1/4

12 1/4, 17

6 1/8

7 7/8, 8 3/4, 12, 12 1/4, 14 3/4

6

6 1/8, 6 3/4, 10 5/8, 17 1/2

12 1/4, 17 1/2

7 7/8, 12 1/4

12 1/4, 14, 16

16

12 1/4

6 3/4

6,12 1/4

8 1/2,12 1/4

8 1/2, 10 5/8, 12 1/4, 13 1/2

14 3/4, 16, 17, 17 1/2

12 1/4

16

8 1/2, 12 1/4, 17 1/2


S619

S716

S719

S816

S819

Si419

Si519

Si613

Si616

Si619

Si819

M413

M416

M419

M509

M511

M513

M516

M519

M609

M613

M616

M619

M711

M713

M716

M809

M813

M816

M909

M916

M1609

8 1/2, 12 1/4, 17 1/2

14 3/4

12 1/4

16, 17 1/2, 26

26

8 1/2

8 1/2, 12 1/4

16

12 1/4

13 1/2

23, 24

7 7/8

6, 7 7/8

8 1/2

3 3/4

4 1/2

4 3/4, 4 7/8, 6 1/8, 6 1/4, 7 7/8

5 7/8, 9 7/8, 11 5/8, 12 1/4, 16

6, 9 7/8, 12 1/4

3 5/8, 3 3/4, 4 1/8, 4 1/2, 4 3/4

6, 8 1/2, 11 5/8, 12 1/4

6 3/4, 9 7/8, 12 1/4

7 7/8, 17 1/2

5 7/8

8 1/2, 8 3/4, 9 1/2, 12 1/4

6, 8 3/8, 12 1/4

6, 6 1/8, 6 3/4

6, 7 7/8, 9, 12 1/4

16

4 3/4, 5 7/8, 6, 6 1/2

8 1/2

8 1/2, 8 3/4

www.slb.com/pdc


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Designed for superior performance when drilling at high rotary

speeds through the toughest, most abrasive formations, Kinetic* bits

are built with precisely engineered grit hot-pressed inserts (GHIs)

and thermally stable polycrystalline (TSP) diamond inserts, premium

PDC cutters, and proprietary diamond-impregnated matrix materials.

Each element is chosen to optimize both durability and ROP.

Application-specific designMost Kinetic bits use strategically placed premium PDC cutters in

the cone area to improve drillout capability and maximize ROP, while

the impregnated matrix material enhances durability. TSP diamond

inserts are positioned on the gauge to ensure that the bit maintains

a full-gauge hole. In extremely abrasive applications, TSP diamond

elements are also placed on the bit shoulder for increased wear

resistance in this critical area. Kinetic bits can be customized with

different bonding materials and diamonds to match the formation

being drilled and the drive system used, making the bits ideal for

exploiting the higher rotational velocities possible with turbodrills.

The bit uses a combination of center-flow fluid distribution and

precisely placed ports to enhance bit cooling and to ensure efficient

bit cleaning. These functions are particularly important in softerformations, enabling the bit to drill mixed lithologies effectively. There

is no need to trip to change the type of bit. Kinetic bits are able to drill

PDC-drillable shoe tracks. They are cost-effective in overbalanced

applications, where drilling with a conventional fixed cutter or roller

cone bit results in low ROP and reduced footage.

A hybrid design, designated with an H in the bit nomenclature, is

a combination of a traditional PDC bit and a diamond-impregnated

bit. Hybrid Kinetic drill bits are suitable in borderline-PDC-drillable

formations.

High performance with turbodrillsBecause of the inherent power and longevity of a turbodrill

compared with a positive displacement motor (PDM), a Kinetic bit

delivers a particularly high performance when combined with a

Neyrfor* high-performance turbodrill system.

Central flow

Open face foroptimum clearing Brazed--in GHI

Cast-in GHI

Dedicated fluidport

Application-tunedimpregnated bodymaterial


K503 5 12 1/4

K505 3 3/4, 5 7/8, 6, 6 1/8, 6 3/4, 8 1/2, 12, 14 3/4, 16

K507 6, 6 1/2, 8 3/8, 8 1/2, 8 3/4, 12 1/4

K703 4 1/2 8 3/4

K705 3 3/4, 6 12 1/4

K707 8 1/2, 14 3/4

KH613 5 7/8, 6KH813 8 3/8, 8 1/2, 9 1/2, 12 1/4

Fixed Cutter BitsKinetic Diamond-Impregnated Bit for High-Speed Applications

www.slb.com/kinetic

Kinetic bits have established world and numerous field records for the most footage drilled andthe highest ROP.

KH 8 1 3Cutter Size

Blade Count

Hybrid

Kinetic Impreg

KineticNomenclature


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L FeatureLow Exposure(MDOC Managed Depth Of Cut)Feature: Cutter backing raised to minimize excessive depth of

cut because of formation heterogeneity.

Advantage: Reduces cutter loading; minimize torque in transitional

drilling.

Benefit: Minimizes cutter breakage and extends bit life.

M FeatureReplaceable Lo-Vibe InsertsFeature: Lo-Vibe* depth of cut control inserts that can be

replaced when needed

(wear, breakage, etc.).

Advantage: Limits excessive depth of cut and helps reduce

torsional vibration.

Benefit: Superior ROP and bit life.

V FeatureLo-Vibe OptionFeature: Lo-Vibe depth of cut control insert.

Advantage: In applications in which bit whirl is a problem, the Lo-

Vibe option improves bit stability and reduces potential

for damage to the cutting structure by restrictinglateral movement and reducing the effects of axial

impacts.

Benefit: Optimized ROP and bit life. Long drilling intervals

without need for tripping.

Fixed Cutter BitsOptional Features


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H FeatureAnti-balling

Feature: Higher number of nozzles than standard.Advantage: Increased cleaning, cooling, and cuttings evacuation

with available hydraulic flows; higher flow rates with

minimal increase in pump pressure, and reduced risk

of bit balling.

Benefit: Superior ROP and bit life; longer drilling intervals

without the need for tripping.

K FeatureImpregnated Cutter BackingFeature: Diamonds impregnated in the matrix behind the PDC

cutters.

Advantage: Limits the progress of PDC cutter wear.

Benefit: Increased footage drilled in abrasive applications.

Z FeatureTSP Diamonds on Leading EdgeFeature: Thermally stable polycrystalline (TSP) diamonds are

placed on the leading edge of each blade.

Advantage: Enhances durability in specific locations on the bit

profile.

Benefit: Increases wear resistance, ensures full-gauge hole,

and extends bit life.



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N Feature

Fewer Nozzles than StandardFeature: Lower than standard nozzle count.

Advantage: Reduced nozzle count to best match drilling, formation,

and hydraulic system capabilities; reduces the flow

rate required to achieve an appropriate hydraulic

horsepower per square inch (HSI); avoids the use of

numerous, smaller nozzles that can become plugged.

Benefit: Superior ROP and bit life; longer drilling intervals


Y Feature30-Series NozzlesFeature: Contains 30-series nozzles.

Advantage: Allows more freedom in cutting structure design,

particularly for smaller bits with limited areas for

placement of larger nozzles.

Benefit: High efficiency for cleaning, cooling, and cuttings

evacuation without compromising the cutting

structure, which could reduce ROP or bit life.

W Feature40-Series NozzlesFeature: Contains 40-series nozzles.

Advantage: Increased thread size for resistance to wear and

erosion.

Benefit: Reduced pop-up force when tightening the nozzle.

U Feature50-Series NozzlesFeature: Contains 50-series nozzles.

Advantage: Maximum adjustable total flow area (TFA) for smaller

or heavier-set designs.

Benefit: High efficiency for cleaning, cooling, and cuttings

evacuation without compromising the cutting

structure, which could reduce ROP or bit life.



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Q Feature

Fixed PortsFeature: Incorporates fixed ports.

Advantage: Optimizes hydraulics in applications where the use of

nozzles compromises the bit design because of space

limitations or other similar reason; provides additional

cleaning of the cutting structure.

Benefit: Improved ROP and bit life.

R FeatureRestrictor Plate in the PinFeature: Nozzle fitted in the pin of the bit in high-pressure-drop

applications.

Advantage: Splits the pressure drop between the nozzle in the pin

and the nozzles on the bit face.

Benefit: Allows installation of larger nozzles in the bit, reducing

nozzle velocity and bit body erosion, extending bit life.

E FeatureExtended Gauge LengthFeature: Longer gauge than standard.

Advantage: Enhances bit stability and allows more area for gauge

protection components.

Benefit: Improved hole quality.



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S Feature

Short Gauge LengthFeature: Short gauge length

Advantage: Reduced bit height improves bit steerability for

directional and horizontal applications. It also reduces

slide time and footage by achieving builds and turns

more quickly.

Benefit: Lower cost per foot, higher overall ROP.

A FeatureActive GaugeFeature: Active gauge.

Advantage: More aggressive side-cutting.

Benefit: Useful for openhole sidetrack applications.

B FeatureBackreaming CuttersFeature: Backreaming cutters.

Advantage: Strategic placement of cutters on the upside of each

blade, to allow backreaming in tight spots, reduces the

potential of bit sticking while pulling out of the hole.

Benefit: Allows a degree of backreaming, sufficient to

condition a borehole without major risk of gauge pad

wear.



35/100

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T FeatureTurbine SleeveFeature: Turbine sleeve.

Advantage: Reduces vibration and hole spiraling in turbine

applications; sleeve lengths can be varied to best

match a specific application.

Benefit: Improved ROP and bit life; long drilling intervals


PXX FeatureFull Diamond Gauge Pad on

Turbine SleeveFeature: Full diamond gauge pad on turbine sleeve.

Advantage: Diamond-enhanced inserts to provide the greatest

possible gauge protection in highly abrasive

formations and underbalanced drilling.

Benefit: In-gauge hole and long gauge life in extreme drilling

environments; longer drilling intervals without the

need for tripping.

PX FeatureDiamond-Enhanced Gauge ProtectionFeature: Diamond-enhanced gauge protection.

Advantage: Thermally stable polycrystalline (TSP) diamonds

provide extra protection to the gauge.

Benefit: In-gauge hole and longer bit life; longer drilling

intervals without the need for tripping.



36/100

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D FeatureDOG Drilling on Gauge SleeveFeature: DOG* drilling on gauge sleeve

Advantage: Reduces hole spiraling.

Benefit: Enhances BHA stability and helps maintain an in-

gauge wellbore.

C FeatureConnection Not API StandardFeature: Nonstandard bit connection

Advantage: Allows nonstandard box connection for a given bit

size, to minimize the length between the bit box and

the turbine or motor pin.

Benefit: Provides stabilization, reduces hole spiraling, and

provides additional gauge protection.

I FeatureIF ConnectionFeature: IF connection replaces the standard connection.

Advantage: Allows the bit to conform to the connection type of

directional tools.

Benefit: Provides more flexibility in configuring a drilling

assembly.



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Product Line Prefix Description

Di IDEAS certified directional designA ARCS & ARCS Advanced

V VertiDrill

S SHARC

C Carbonate

HOX Heavy Oil Series

M Matrix Body

S Steel Body

K Kinetic Impregnated Bit

H Kinetic Hybrid Bit

D Natural Diamond Bit

L LIVEPR Pilot Reamer

T Turbine

ST Side Track

SHO Staged Hole Opener

QD Quad-D Dual Diameter

G Reamers with API Connections (box down, pin up)

R Reamers with IF Connections (


38/100


39/100

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Roller Cone Products


40/100

36

Tungsten Carbide Insert (TCI) bits- Gemini* dynamic twin-seal drill bit

- Shamal* carbonate-optimized TCI drill bit

- Xplorer* slimhole TCI drill bit

- FH TCI* drill bit

Milled Tooth (MT) bits- Xplorer Expanded* soft-formation milled tooth drill bit

TCT* two-cone drillbit technology

Standard roller cone bits - Milled tooth, TCI, and open-bearing bits for all applications

Roller Cone Bits Product Line


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Roller Cone BitsGemini Dynamic Twin-Seal Drill Bit

The Gemini seal system consists of a primary seal that protects the bearings, and a secondaryseal that protects the primary seal, making this system the industry leader in durability andreliability.

8 3/8 in GF15, GF20, GF40, GFi50

8 1/2 in GF05, GF06, GF08, GF10, GF15, GF20,GF25, GF30, F30, GF40, GF45,

GF50, GF65, GF80, GFA21, GFi08, GFi10, GFi12, GFi20, GFi23, GFi28,

GFi30, GFi45, GFi50

8 5/8 in GF15, GF45

8 3/4 in GF10, GF15, GF27, GF40

9 1/2 in GF20, GF21, GF30, GF45, GFVH

11 5/8 in GF15, GF20

12 in GF10, GF20, GF28

12 1/4 in G04, GF05, GF10, GF15, GF20, GF26, GF30, GF37, GF40, GF45, GF47,

GF57, GFi05, GFi06, GFi12, GFi23, GFi28, GFi30, GFi35, GFi40, GFi45,

GFi47, GFK30, GFK57, GFKi28, GGH+, MGGH+

14 3/4 in G10, G15, G25, G40

16 in G18, GGH+, MGGH+

17 1/2 in G02, G10, G15, G28, G30, Gi01, Gi03, Gi12, GGH+

22 in Gi06

24 in G04

26 in G04, G28

The proprietary dual-material primary seal

combines a highly wear resistant, dynamic

face elastomer and a softer energizing

material that exerts a consistent contact

pressure. The bullet-shaped seal has a large

cross-sectional profile to provide maximum

protection for the bearing.

The secondary seal is also made from a mix

of patented materials, and is designed to

prevent abrasive particles in the wellbore

fluids from coming into contact with the

bearing seal. A thermoplastic fabric

reinforced with Kevlar is positioned on the

dynamic face, embedded in an elastomer

matrix. The fabric provides resistance to

wear and tear, and heat damage, in addition

to acting as a barrier to abrasive particles.

The elastomer matrix provides elasticity and

proven sealing ability.

Although they work independently, the sealscreate a synergy that allows them to

17 1/2-in Gi03

G F i 3 5Cutting structure

i - IDEAS certified

Gemini Designation

GeminiNomenclature

www.slb.com/gemini

perform reliably for extended periods of time

at higher RPMs, heavier drillstring weights,

extreme dogleg severity, and increased mud

weights and pressures. Gemini* drill bits are

available in a wide range of sizes, as both

TCI and milled tooth bits.

BearingsGemini bits can be equipped with roller

bearings (bit size 12 in) or friction

bearings (bit size 12 in).

Cutting StructureDifferent cutter layouts are available. TCIs of

various grades and geometries have been

developed to produce a durable and

effective cutting structure. IDEAS*

integrated drillbit design platform is used to

optimize the cutting structure, so that loads

are more evenly distributed over the inserts

of all three cones, producing a well-

balanced bit with reduced risk of bearingfailure.


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The Shamal* product line incorporates a

range of TCI bits developed for maximizing

performance in hard carbonate formations.

These bits use a range of proprietary, coarse

carbide grades, which are designed to

combat heat checking and subsequent

chipping and breakage of inserts, the

primary dull characteristics when drilling

hard carbonates.

Incorporating unique cone layouts and insert

geometries, the Shamal product line is

providing superior ROP and durability in

challenging

applications throughout the world.

Roller Cone BitsShamal Hard Carbonate-Optimized TCI Drill Bit

12-in GFS05BVCPS

G S i 0 5XX Cutting Structure

i - IDEAS certified

Shamal Feature

Bearing Prefix

ShamalNomenclature

8 1/2 in GFS05, GFS06, GFS15, GFS20, GFS30, GFSi10, GFSi23, GFSi28,

MFS04, MFS10T, MFS20B

8 3/4 in GFS15

11 5/8 in GFS30

12 in GFS28

12 1/4 in GFSi01, GFS04, GS04, GFS05, GS05, GFS06, GFSi06, GFS10,

GS10, GFS11, GFS15, GS15, GFS20, GFS26, GFS30, GFSi28

14 3/4 in GS10

15 1/2 in GS1016 in GS03, GS10, GS12, GS18, GS30, GSi01, GSi03, GSi06, GSi12,

GSi15, GSi18, GSi20

17 1/2 in GS03, GS05, GS10, GS12, GS15, GS18, GS28, GSi01, GSi12, GSi18

22 in GS04, GS12, GSi06, GSi12

23 1/2 in GS04

24 in GS18

26 in GS04, GS18

28 in GS04, GS18, GSi18

36 in GSi15

Shamal tungsten carbide

www.slb.com/shamal

Shamal drill bits are designed for hard carbonate drilling, with specifically designed tungstencarbide inserts.


43/100

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Roller Cone BitsXplorer Premium Slim Hole TCI Bit

Xplorer drill bits provide consistently superior performance in applications ranging from verysoft to ultrahard formations.

Maximum steerability and strengthXplorer* slimhole TCI drill bits have ultrashort leg forgings, which

maximize steerability at extreme build angles, enabling the most

demanding directional programs. The forging design also

strengthens the chassis and meets the hydraulic demands of modern

drilling.

Harder-wearing seals

To handle the high rotation speeds typically seen in the formations inwhich slimhole bits are used, a dual-material Bullet* drillbit bearing

seal is used for soft formation insert bits (IADC 4-1-7X to 5-4-7Y). This

system reduces seal wear while limiting temperature buildup in the

bearing section through the use of matched, dual elastomers.

X R i 2 0

XX - Cutting Structure

i - IDEAS Certified

Xplorer Nomenclature

XplorerDesignation

3 3/4 in XR20, XR40

3 7/8 in XR30, XR50

4 1/8 in XR30, XR50

4 1/2 in XR30

4 5/8 in XR30, XR50

4 3/4 in XR15, XR20, XR30, XR40, XR50, XR70

4 7/8 in XRi15, XR20, XR30, XR50

5 1/2 in XR20, XR40

5 5/8 in XR30, XR40, XR50

5 7/8 in XR15, XR20, XR30, XR40, XR50, XRi40, XRi50, XRS15

6 in XR10, XR12, XR15, XR20, XR30, XR40, XR45, XR50, XR65, XR70,

XRS30, XRi15, XRi20, XRi40, XRi45, XRi50

6 1/8 in XR10, XR15, XR20, XRSi20, XR25, XR30, XRi30, XRi35, XR38, XR40,

XR50, XR60, XRi65, XR68, XR70, XR90, XR35, XRi20, XRi28, XRi40,

XRi45, XRi50, XRKi65

6 1/4 in XR20, XR30, XR40, XR50, XR70, XRi30, XRi35, XRi45

6 1/2 in XR10, XR15, XR20, XR30, XR40, XR45, XR50, XR60, XR68,

XR70, XR90

6 3/4 in XR10, XR20, XR25, XR32, XR40, XR50, XRi30

6 1/2-in XR20T

www.slb.com/xplorer

For harder formation Xplorer bits (with IADC codes 6-1-7X and

higher), a rotary O ring seal with optimized properties is used,

which significantly increases the wear resistance of the seal

compared to conventional materials. These O rings result in

market-leading bearing performance in hard formations.

Optimum cutting structuresIndividual cutter layouts, as well as a complete range of inserts,

insert grades, and geometric enhancements have been developed

specifically for Xplorer bits to reduce breakage, maintain full gauge,

and increase ROP. Features such as Ridge Cutters* drillbit chisel

inserts, significantly reduce cone shell wear and allow the main

cutting structure to function more effectively.


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Milled tooth drill bits that are specifically designed to drill soft to firm formations.

X R +

XX - Premium Milled Tooth Cutting Structure

Xplorer Nomenclature

XplorerDesignation

Enhanced ROPXplorer Expanded* milled tooth drill bits are specifically designed to

drill soft to firm formations with superior ROP and reliability. The bits

are equipped with the Flex-Flo* adaptive hydraulics system, offering

the widest range of options for maximizing ROP and ensuring

effective hole cleaning in any application.

Extremely wear resistant MIC2* drillbit hardfacing material provides

durability, enabling the bits to drill at a high ROP for prolonged

periods. The cutting structure is designed for for maximum shearing

and scraping action in the softer formations encountered in milled

tooth applications.

Reliable seals and bearingsAll Xplorer Expanded bits with 8 1/2-in or larger diameter benefit

from the proven reliability of the dynamic twin bearing-seals system

used by Gemini* drill bits. The Spinodal* roller cone drillbit friction

bearing used is both reliable and durable. Bit sizes 13 in and

greater incorporate premium sealed roller bearings.

Roller Cone BitsXplorer Expanded Soft-Formation Milled Tooth Drill Bit

17 1/2-in XR+ ODVEC

XR+, in 4 1/2, 4 3/4, 4 7/8, 5, 5 1/2, 5 5/8, 5 3/4, 5 7/8, 6, 6 1/8, 6 1/4,

6 1/2, 6 3/4, 7 7/8, 8 3/8, 8 1/2, 8 3/4, 9 1/2, 9 7/8, 10 5/8, 11 5/8,12 1/4, 13 1/2, 13 3/4, 14 1/2, 14 3/4, 15, 15 1/2, 16, 17, 17 1/2,

18 1/8, 18 1/2, 19 1/4, 20, 21 3/4, 22, 23, 24, 26, 31, 32, 32 1/4,

32 3/8, 33, 36

www.slb.com/xr-expanded


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Roller Cone Products for Geothermal and High-Temperature Applications

Geothermal and high temperature drill bits

High temperature drilling environments, seen most commonly in

geothermal wells, provide a unique set of challenges for downhole

equipment. In many of these applications the tungsten carbide

insert (TCI) roller cone bits used to drill these wells must endure hard

and abrasive formations to steam or hot rock in basement

formations where temperatures can exceed 500 degF.

At that temperature, a standard 300 degF-rated bits elastomer seals

and lubricating material quickly degrades, causing bearing failure,

resulting in operational inefficiencies: reduced on-bottom drilling

hours leading to multiple bit runs/trips, and increased development

costs.

Drilling for unique energy calls for a unique bitKaldera high-temperature roller cone drill bit represents a new line

of bits with an innovative bearing system that comprises new propri-

etary composite elastomer seals with specialized fabric compounds

and a proprietary high-temperature grease formula. These innova-

tions increase seal life, lubricity, and load capacity at elevated

temperatures for HT applications.

Proven durability in high-temperature applicationsTested against baseline bits, in geothermal superheated steam appli-

cations where temperatures can reach 530 degF, the new Kaldera

roller cone bit was clearly the top performer:

On-bottom drilling time was 3% to 37% greater

Average run length was 33% greater

Roller Cone BitsKaldera

www.slb.com/kaldera

6 in XRK40

6 1/8 in XRK40

7 7/8 in FHKi30

8 1/2 in 47YGA, FHK15, FHK30, FHK45, FHKi40, FHKi50, FHKi69

9 7/8 in FHK30, FK47, FK50, FK57

10 5/8 in GFK47

12 1/4 in 47YG, GFK15, GFK30, GFKi28, GFK10

17 in GSK20, GSKi18

22 in GSKi12

5 7/8 in XRK+

8 1/2 in XRK+

Milled Tooth

TCI

Kaldera Nomenclature

Milled Tooth

X R K +

XX - Premium MilledTooth Cutting Structure

Xplorer -Kaldera

Designation

G F K 47

XX - Premium TCICutting Structure

Gemini -Kaldera

Designation

TCI


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Roller Cone BitsFH Single-Seal TCI Drill Bit

FH TCI roller cone drill bits offer superior performance in a wide variety of applications at alower cost per foot.

Optimized cutting structureFH* TCI drill bits have patented insert and cutter geometries.

Engineers use the IDEAS* integrated drillbit design platform to

precisely monitor the interaction between the cutting elements and

the rock, and optimize bit design to allow the maximum amount of

mechanical energy to be applied to the formation.

Reliable seals and bearingsThe bullet-shaped, dual dynamic seals of FH TCI bits have undergone

extensive finite element analysis (FEA) in a laboratory to ensure

reliability. The bearings used are the latest evolution of the silver-

plated Spinodal* roller cone drillbit friction bearings. The proven

properties of the bearing material, along with the friction-reducing

effects of the silver, combine to create a longer lasting, highly reliable

bearing package.

Application-specific hydraulicsThe Flex-Flo* adaptive hydraulics system offers a range of hydraulic

configurations that are optimized for specific applications.

Computational fluid dynamics software, and our bit flow visualization

system were used to design this feature.

F H i 2 8


i - IDEAS Certified

FH Nomenclature

FHDesignation

8 3/4-in FH28GVPS7 7/8 in FHi20, FHi21, FHi23, FHi24, FHi26, FHi28, FHi30, FHi35, FHi38,

FHi40, FHi45, FHi50, FHi43, FHKi30, FH25, FHi08, FHi18,

FHi37, FHi39

8 1/2 in FH23, FHi04, FHi20, FHi21, FHi28, FHi40, FHi69, FH30, FH35,

FH40, FH45, FH50, FHi90, FHK08, FHK30, FHKi 40, FHKi50,

FHKi69

8 3/4 in FH16, FHi18, FH20, FHi20, FHi21, FHi23, FHi25, FH28, FHi28,

FHi29, FHi30, FH32, FHi35, FHi37, FHi38, FHi40, FH43, FH45,

FHi50, FH23, FH30, FH35, FH40, FH50, FHi32, FHi39, FHi43,

FHi45, FHi47, FHi55, FHi90

9 7/8 in FH23, FH28, FH30, FH35, FH40, FH45, FH50, FHi12, FHK30

12 1/4 in FH24, FH50

www.slb.com/FH


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Roller Cone BitsTCT Two Cone Drillbit Technology

Smith Bits TCT* two-cone drill bits are designed using the dynamic

modeling capabilities of the IDEAS* integrated drillbit design

platform. The process includes evaluation and testing in a virtual

environment to reduce vibration, enhance stability, and increase ROP.

Optimal cutting structureExtensive analysis ensures that the cutting structure layout optimally

exploits the bits unique characteristics. Two-cone bits have lower

tooth counts than equivalent three-cone bits, and higher point

loading per tooth for improved formation penetration. They also

benefit from current technology for enhanced insert geometries and

the latest carbides and hardfacing materials.

Five-nozzle hydraulic configurationTCT two-cone drill bits can incorporate five nozzles, four outboard

and one center jet. The field-proven V-Flo* vectored-flow nozzle

configuration precisely positions and directs the five nozzles for

increased impingement pressure and optimum cutting structure

cleaning and cuttings evacuation, thereby improving penetration

rates. The five-nozzles significantly increase the available options for

directing fluid flow, compared with a three-cone bit that uses three

nozzles.

Enhanced stabilityTwo-cone bits have four points of stabilization. The lug-pad and leg-

back placement, along with the forging geometry, reduces vibration,

increases bit life, and enables a higher ROP. In addition, the lug pads

and leg backs are protected by tungsten carbide inserts to stabilize

the bit and ensure a full-gauge wellbore.

Reliable twin-seal systemThe dynamic twin-seal system of Gemini* bits is also employed by

TCT two-cone drill bits. It comprises a pair of seals working together

to provide the most reliable and robust sealing mechanism available

in roller cone bits. The bits maintain seal integrity under the harshest

conditions, including high rates of rotation, weight on bit, dogleg

severity, mud weights, temperature, and pressure.

6 1/2 in TCTi+

7 7/8 in TCTi20

8 1/2 in TCTi+

8 3/4 in TCTi+, TCT20, TCT37

9 7/8 in TCTi+

12 1/4 in TCTi+, TCT11, TCT12, TCTi11

16 in TCT+, TCTi+

17 1/2 in TCT10, TCTi+

T C T i +

XX - Premium MilledTooth Cutting Structure

i - IDEAS Certified

TCT Nomenclature

TCTDesignation

12 1/4-in TCI TCTi

12 1/4-in MT TCTi+

www.slb.com/tct

More aggressive roller cone designs


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The standard line of Smith Bits journal and roller bearing bits delivers premium performance.These bits are the focus of ongoing product improvement, which enhances existing designs andintegrates new materials technology.

Roller Cone BitsStandard Milled Tooth, TCI and Open Bearing Bits

Standard bits are continuously improved in order to aggressively

drive down drilling costs. Among the features and materials

incorporated into the standard product offering are Spinodal* roller

cone drillbit friction bearings, advanced bearing lubricants, the

Flex-Flo* adaptive hydraulics system, MIC2* drillbit hardfacing

material, diamond-enhanced inserts, coarse carbide inserts, and

relieved-gauge inserts.

3 3/4 in OFH, OFM

6 3/4 in

6 in FDGH, FHV

7 1/2 in FDT

7 7/8 in FDS+, FI18, F26Y, F27Y, F27iY, F30Y, F37HY, FI39HY, F45H, F47HY,

F47YA, F49YA, F57Y, F59HY, F67Y, F80Y, F85Y, F90Y

8 3/8 in MFDGH, SVH, F37Y, F57Y

8 1/2 in F10, F37HY, F37Y, F47HY, F57Y, F67Y, F80Y, F85Y,

FDGH, FDS+, MFDGH

8 3/4 in FDS+, F12V, F26Y, F27iY, F30T, F37HUY, F37HY, F39HY, F40YA, 46HY,

F47HY, F47YA, F50YA, F59Y, F67Y, F80Y, F85Y, F90Y

8 7/8 in F40YA, F50YA

9 1/2 in FDS+

9 7/8 in FDS+, F10B, F37Y, F47HY, F59Y, F67Y, F80Y, F85Y, F90Y

10 5/8 in F37, F47Y, F67Y, F85Y, F90Y

11 in F20, F20Y, F27Y, F37Y, F47Y, FDS

11 5/8 in F30, F47Y, FDGH, MSVH

12 1/4 in F25Y, F37Y, F40, F47YA, F57, F67, F80Y, F90Y, FDGH, FDS+, FDT

14 3/4 in F30

17 in MSDGH

17 1/2 in DSJ

20 in MSDGH

22 in MSDGH

23 in DSJ, MSDGH

26 in DSJ, MSDGH

28 in MSDGH, DSJ

32 in MSDSSH

34 in MSDGH

36 in DSUJ

12 1/4-in FVH

Standard Nomenclature/Milled Tooth Bits

F V H

Heel Inserts

Medium to Hard Formation Type

Bearing Prefix

8 3/4-in F12

Standard Nomenclature/TCI Insert Bits

F 1 2


Bearing Prefix

www.slb.com/rockbits


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D FeatureDiamond-Enhanced Gauge Row InsertsInsertsFeature: Diamond-enhanced gauge inserts.

Advantage: Significantly lower gauge-row wear and breakage

rates, and greater wear-resistance in highly abrasiveapplications.

Benefit: High-quality, full-gauge wellbore over significantly

longer intervals compared with tungsten carbide

gauge inserts.

TD FeatureDiamond-Enhanced Trucut

Gauge ProtectionFeature: Diamond-enhanced, semiround-top, on-gauge inserts

provide the finish cut-to-gauge for Trucut* drillbit

gauge system. Off-gauge inserts are made of tungsten

carbide.

Advantage: Suitable for more abrasive environments; more

durable than standard Trucut gauge configuration.

Benefit: Extended bit-gauge life results in long intervals of

quality, in-gauge borehole.

SD FeatureShaped Diamond-Enhanced Gauge InsertsFeature: 100% shaped diamond-enhanced gauge inserts.

Advantage: Shaped geometry creates a more aggressive cutting

structure.

Benefit: Maximum ROP and high-quality, in-gauge borehole for

the longest possible intervals in highly abrasive

environments.

Roller Cone BitsOptional Features


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B Feature

Binary Gauge ProtectionFeature: Small, semiround-top inserts positioned between

primary gauge inserts.

Advantage: Smaller inserts improve wear resistance.

Benefit: Improved bit-gauge durability and longer, in-gauge bit

runs.

BD FeatureDiamond-Enhanced Insert Binary

Gauge ProtectionFeature: Diamond-enhanced, semiround-top inserts positioned

between primary gauge inserts.

Advantage: Extreme wear resistance.

Benefit: Improved bit-gauge durability and longer, in-gauge bit

runs.

T Feature

Tungsten Carbide TrucutGauge ProtectionFeature: TCI protection for Trucut* drillbit gauge system.

Advantage: Improved gauge durability and integrity with a twin

gauge-insert system composed of aggressive, near-

gauge inserts to drill the near-gauge and borehole

corner with reduced scraping action, and semiround-

top, on-gauge inserts that provide the finish cut to

gauge; significantly reduced stress on gauge inserts.

Benefit: Extended bit-gauge life for long intervals of quality, in-

gauge borehole.

OD FeatureDiamond-Enhanced HeelRow InsertsFeature: Up to 50% diamond-enhanced heel row inserts.

Advantage: Improved resistance to abrasive wear and impact

damage; protection for the lower leg and bearing seal

areas.

Benefit: Longer gauge-cutting-structure life for long intervals

of high-quality, full-gauge borehole.



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OD1 FeatureAll Heel Row Inserts DiamondEnhancedFeature: 51%100% diamond-enhanced heel row inserts.

Advantage: The heel cutting structure is designed for the most

abrasive environments, resulting in a longer gauge-

cutting-structure life, and rotection for the lower leg

and bearing-seal areas.

Benefit: Longer intervals of high-quality, full-gauge borehole in

highly abrasive, high compressive strength formations.

DD Feature100% Diamond-EnhancedCutting StructureFeature: 100% diamond-enhanced cutting structure.

Advantage: Premium cutting structure for drilling very abrasive

formations efficiently, with longer runs and lower

weight on bit (WOB).

Benefit: High ROP and extended bit life.

G Feature

Super D-Gun Cone ProtectionFeature: Super D-Gun* tungsten carbide cone protection.

Advantage: A hard, tungsten-carbide-based coating applied to

cone shells makes them unusually resistant to

abrasion and erosion. This feature is ideal for highly

abrasive formations that generate large volumes of

cuttings. It is also helpful in abrasive conditions with

inefficient hole cleaning such as high angle,

directional, and horizontal applications.

Benefit: Increased bit life, longer bit runs, and improved insert

retention.



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Y Feature

Conical Shaped InsertsFeature: Conical shaped inserts.

Advantage: Geometry optimized to reduce insert breakage.

Benefit: High ROP in formations which are sensitive to weight

on bit (WOB).

V FeatureV-Flo Nozzle ConfigurationFeature: V-Flo* vectored-flow nozzle configuration

Advantage: Jets are directed at the leading side of the following

cone for maximum cleaning; enhanced bottomhole

cleaning is achieved through efficient cuttings lift and

establishment of a strong, upward, helical flow.

Benefit: A clean cutting structure in soft and sticky formations.

VE Feature

Extended Vectored Nozzle Sleeve(Available for 12 1/4-in and larger bits)Feature: Extended vectored nozzle sleeve.

Advantage: The angles of the nozzles are precisely oriented to

direct fluid flow to the leading edge of the cones,

resulting in the most efficient cleaning.

Benefit: Clean cutting structure, and maximum ROP through

higher impingement pressure.



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J3 Feature (Dome Jets)(Available for 16-in and larger bits)Feature: Three nozzles located inboard of conventional roller

cone nozzle positions.

Advantage: Flow is directed toward the intermesh area between

the cones to enhance cone cleaning.

Benefit: Increased cone cleaning to prevent bit balling and

maximize ROP.

C FeatureCenter JetFeature: Center jet installed.

Advantage: Enhanced cone cleaning and hydraulic flow patterns

across the bit cutting structure.

Benefit: Clean, efficient cutting structure in high-cuttings-volume or sticky formations.

L FeatureLug-Type Leg Back ProtectionFeature: Shaped steel-pads welded to the upper leg back, with

flush-set tungsten carbide or shaped diamond-

enhanced inserts.

Advantage: Leg protection and bit stabilization; helps prevent bit

whirl and differential wear between bit legs, which

can overload individual cone cutting structures and

bearings.

Benefit: High quality wellbore and extended bit life.



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R FeatureSemiround-Top (SRT) TCI Stabilization &Leg Back ProtectionFeature: Stabilizing leg back protection.

Advantage: Cluster of SRT tungsten carbide inserts, located on the

upper leg section and extending to near full-gauge,

enhance wear protection and improve bit stability.

Benefit: Extended bit life and improved borehole quality.

PS FeatureSemiround-Top (SRT) TCI Leg BackProtectionFeature: Leg back protection.

Advantage: Strategically placed, SRT tungsten carbide inserts

improve leg protection against wear; tight, overlapping

pattern helps prevent grooving of leg backs.Benefit: Extended bit life in abrasive environments.

PD FeatureDiamond-Enhanced Leg Back ProtectionFeature: Diamond-enhanced leg back protection.

Advantage: Strategically placed, SRT, diamond-enhanced and

tungsten carbide inserts improve leg protection

against wear; tight, overlapping pattern helps prevent

grooving of leg backs. This configuration is more

wear-resistant than 100% tungsten carbide protection.

Benefit: Extended bit life in extremely abrasive environments.



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Bearing/Seal

Identifier & Product

Line Prefix Applies To Refers To Description

D All Bearing/Seal Nonsealed (open) bearing

S All Bearing/Seal Single seal, sealed roller bearing

F All Bearing/Seal Single seal, sealed friction bearing

MF All Bearing/Seal Single seal, friction bearing motor bit

M All Bearing/Seal Single seal, roller bearing motor bit

K All Bearing/Seal High temperature seals (geothermal applications)

G All Product Line Gemini* bit, twin seal, roller bearing

GF All Product Line Gemini bit, twin seal, friction bearing

XR All Product Line Xplorer* slimhole TCI bit (up to 6.75 in)

Xplorer Expanded* soft-formation milled tooth bit (up to 36 in)

TCT All Product Line TCT* two-cone technology bit

FH TCI Product Line FH TCI*bit, single seal, sealed friction bearing

S TCI Cutting Structure Shamal* carbonate-optimized design, with or without Typhoon hydraulics

i All IDEAS Design certified by IDEAS* integrated drillbit design platform+ MT Cutting Structure Milled tooth designator / Premium cutting structure

DS MT Cutting Structure Soft type (IADC 1-1-X) - applicable to FDS bits only

DG MT Cutting Structure Medium type (IADC 1-3-X) - does not apply to Gemini bits

S MT Cutting Structure Soft type (formerly DS) - D and G products only

T MT Cutting Structure Medium soft type (formerly DT)

G MT Cutting Structure Medium type (formerly DG) - D and G products only

V MT Cutting Structure Medium hard type (formerly V2)

S MT Cutting Structure Premium self-sharpening with hardfacing material

H MT Carbide Gauge Nonpremium bit - heel inserts

B TCI Carbide Gauge Binary carbide gauge

H TCI Carbide Gauge Heavy-set gauge design (count or grade or both)

T TCI Carbide Gauge Trucut* gauge (carbide material on both off-gauge and gauge)

00-99 TCI Cutting Structure Insert bit numeric range (00 Softest - 99 Hardest)

Product Suffix Applies To Refers To: Description

I TCI Cutting Structure Inclined chisel on gauge

W TCI Cutting Structure Softer than standard insert grades

Y TCI Cutting Structure Conical insert

A All Cutting Structure Air application bit

N All Size Nominal gauge diameter

Feature Applies To Refers To: Description

TD TCI Diamond Gauge Trucut diamond with diamond-enhanced inserts (DEI on gauge; carbide on off-gauge)

SD TCI Diamond Gauge Shaped diamond-enhanced gauge inserts and 20% to 50% heel inserts

SD1 TCI Diamond Gauge Shaped diamond-enhanced gauge inserts and 51% to 100% heel inserts

D TCI Diamond Gauge Semiround top (SRT) diamond-enhanced gauge inserts

OD All Diamond Heel 20% to 50% diamond-enhanced heel row inserts

OD1 All Diamond Heel 51% to 100% diamond-enhanced heel row insertsDD TCI Full Diamond Diamond-enhanced cutting structure (nose, middle and gauge inserts)

DD2 TCI Full Diamond Diamond-enhanced cutting structure, (nose, middle and premium gauge inserts)

G TCI Cutting Structure Super-D Gun tungsten carbide insert cone-shell protection

Q All Hydraulics Q-Tube hydraulics

V All Hydraulics V-Flo vectored-flow nozzle configuration

E All Hydraulics Extended nozzle tubes

VE All Hydraulics Vectored extended nozzle tubes

J3 All Hydraulics Dome jets (3 jets in the bit dome)

C All Hydraulics Center jet

L All Leg Protection Lug pads with tungsten carbide inserts

LD All Leg Protection Lug pads with diamond-enhanced inserts

R All Leg Protection Upper legback semiround top (SRT) TCI cluster and PS feature

RD All Leg Protection Upper legback semiround top (SRT) DEI cluster and PD feature

PS All Leg Protection Semiround top (SRT) tungsten carbide leg protection

PD All Leg Protection Semiround top (SRT) diamond-enhanced leg protection

P All Leg Protection Modied PS feature pattern; Note: West Texas bits only

Roller Cone BitsNomenclature


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Percussion Hammers and Bits


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Impax hammer unifies durability and performance for deep-hole drilling

HammersPercussion Hammers

The Impax* hammer features a patented hardened-steel guide

sleeve that significantly optimizes energy transfer between the

hammers piston and bit. The guide sleeve design also significantly

improves deep-hole drilling reliability by eliminating the plastic blow

tube: a component that often causes conventional hammers to fail

when they are subjected to shock, vibration, abrasive wear, and

high-temperature erosion caused by misting.

Because high-back pressure, circulation volume, and the water

produced from misting and influx are major causes of hammer bit

failure, the Impax hammers lower chamber has been designed to

handle 10% to 20% more water than conventional hammer bits.

When water incursion forces those bits to be tripped out of the well,

the Impax hammers combined capabilities enable it to endure deep-

hole drilling conditions while delivering reliable performance.

Impax hammers are available in 8-, 10-, and 12-in sizes.

Impax Retention SystemImpax bits proven retainer design protects the bit head from being

lost downhole, thereby eliminating sidetracking or fishing costs.

1. A set of split retaining rings at the top of the bit ensure

Bits Catalog

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