Bits Catalog

2012 Product Catalog

Headquarters1310 Rankin Rd.Houston, TX 77073-4802www.slb.com

Copyright 2011 Schlumberger. All rights reserved.

No part of this book may be reproduced, stored in aretrieval system, or transcribed in any form or by any means electronic or mechanical, including photocopying andrecording without the prior written permission of thepublisher. While the information presented herein isbelieved to be accurate, it is provided as is withoutexpress or implied warranty.

Specifications are current at the time of printing.

11-BT-0027

An asterisk (*) is used throughout this document to denotea mark of Schlumberger. Other company, products andservice names are the properties of their respective owners.

Table of Contents

Technological Expertise 1 17Innovative Smith Bits technology for every stage of drilling

Fixed Cutter Bits 19 33A wide range of PDC and diamond-impregnated bits

Roller Cone Bits 35 50A comprehensive selection for various applications

Percussion Hammers and Bits 53 56Impax hammer products designed for oilfield applications

Borehole Enlargement 59 71An extensive catalog of robust and reliable tools

Reference Guide 73 93

1Technological Expertise

2Engineering 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 of the drilling program, from planning to execution

3The 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 system analysisThe 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 a specific 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 rigorous design evaluation and testing to produce a detailed application analysis of how it will perform for a specific drilling program.

Rapid solutions with reliable resultsBy 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 to deliver a better solution faster.

DefinePerformanceObjectives

IDEAS Simulation Design Test Analyze

Build Bit

Test Bit

Certify Bit

Integrate new bit into product line

The IDEAS Platform

www.slb.com/IDEAS

4Extensive 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 stable bit 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

5Efficient 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 bit performance and choose the optimum solution.

Engineering and ModelingComputational Fluid Dynamics (CFD) Analysis

6i-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 downhole behavior 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 bitrock 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 diverse sources 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 Identifythetruetechnicallimitofperfor-

mance without risking lost rig time associ-ated with exceeding the limit or inefficien-cies resulting from operating too far below the limit.

EliminateunnecessarytripstochangeBHAs when trying to identify the optimum drilling system .

Predicttheperformanceofnewdrillbitdesigns.

Predictthedynamicbehaviorofdirec-tional BHAs in space and time.

IdentifyweakareasinthedrillstringandBHA to help prevent the loss of tools downhole.

Minimizeharmfullateral,torsional,andaxial vibrations; and stick/slip, through the selection of dynamically stable drilling assemblies.

Balancedrillbitandunderreamercuttingstructure loading to maximize dual-diam-eter BHA stability.

Developimproveddrillingprogramsched-ules with reduced risk of unplanned delays.

i-DRILL analysesThe following analyses are available: drillingsystemchecktoevaluatedynamic

behavior; identify issues with vibration, bending moments, and torque; and select the optimal system

bitanalysistoidentifythedesignthatwillyield the highest ROP under stable condi-tions

bitdurabilityandROPthroughdifferent formations.

bit-underreamerbalancetodeterminethecombination that will result in the highest ROP under stable conditions

BHAcomparisontoinvestigatedirectionalbehavior while minimizing vibrations

rangeofweightonbit(WOB)anddrillbitrevolutions per minute (rpm) for maximum ROP under stable conditions

postwellfollow-uptodetermineusageandeffectiveness of prewell i-DRILL design recommendations

Maximize performance with a dynamically stable drilling assembly.

7The 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 special drilling 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 while drillingTo 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.

8Post 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

9Engineering 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 deliverablesVarious levels of analysis are offered, and for each level, data is presented 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 wirelineorLWDformationevaluationdata rock type and strength data hydraulic and mechanical energy factors. Neural networks, planned run simulation and real-time optimization Neural 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 InternetconnectionandtheWeb-basedwellsiteinformationtransferstandardmarkuplanguage(WITSML),byauthorizedwellsiteproviders 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.

WellsiteserviceproviderscancontributeexpertisetothecommonstoreviatheWITSMLinterface,andthenquerythedatastoreforcombined information from other wellsite services. This information can support program analysis, visualization, and potential corrective actions, 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 ofvendors,viewandmonitorcurrentwellsviaWeb-basedapplications, 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.Withthisdetaileddataandthecapa-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 rightbitisruninagivenformation.Withthisplan 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 the toughest drilling applications

New technology increases performanceWhentheONYX*PDCcutterwasintroducedits 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 laboratory evaluationA continued investment in the most advanced component testing facilities by Schlumberger has 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 has evolved over the years to enhance the perfor-mance of PDC bits. Wear characteristics have been evaluated in controlled laboratory simulations on granite, and ONYX II shows significantly improved resistance to abrasion, as measured against previous gen-erations of PDC cutters. (above cutters shown after standard granite abrasion test)

Resis

tanc

e to

Abr

asio

n

ONYX2009

ONYX II2011

Second generationpremium 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 varyingdegrees.WiththeFlex-Flo*adaptivehydraulics system, Smith Bits offers the ideal configuration for each application

Very soft and/or sticky formations that generate very large volumes of

cuttings with Milled Tooth bits and very

soft TCI bits.

Zone 1Low strength

formations that generate large

cuttings volumes and drill with soft

TCI bits.

Zone 2

Medium strength formations that

generate moderate cuttings volumes with mediumhard

TCI bits.

Zone 3

High strength formations that generate low

cuttings volumes with hard TCI bits.

Zone 4

Soft/StickyHard/Abrasive

Cutting Structure Cleaning Bottom-Hole Cleaning Cuttings Evacuation

Hydraulic Function vs. Formation

Hyd

raul

ic F

unct

ion

Nee

d

V-FloV-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-FloThe many variations of X-Flo* crossflow nozzle configuration allocate available hydraulic energy to improve penetrationrates through cone cleaning and dramatically increased impingement pressure, needed for superior bottomhole cleaning.

S-FloIn 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 softtoveryhard.Withineachzone,therela-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 a Smith 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 with Typhoon hydraulics incorporate three vectored extended (VE) nozzles and three dome jet (J3) inner nozzles to apply maximum hydraulic energy to the bottom of the wellbore, enhancing cuttings removal and 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.

16

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 ChoicesSmith Bits pioneered the use of specific insert shapes in 1995, and uses 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,andDogBonedesigns.Withasharpoffset,C-shapedcrestand 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

17

Diamond-Impregnation Grit 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 cutwitheachrotationofthebitisverysmall.Whiledrilling,GHIscontinuously 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 period of time.

19

Fixed Cutter Products

20

Directional PDC Drill Bit Matrix or steel drill bits for improved directional response

SHARC* High-Abrasion-Resistance PDC Drill Bit Matrix 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 D i 6 1 6Cutter Size Blade 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 7/8

MDi616 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 1/2

MD816 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

22


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, 12

MSi519 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 S i 6 1 9Cutter Size Blade Counti - IDEAS Certified

S - SHARC

D - IDEAS Directional CertifiedM/S - Matrix or Steel

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.

Whendrillinghard,highlyabrasiveformations,SHARCPDCbitsmaintain 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

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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 3Cutter Size Blade Count

i - IDEAS Certified

D - IDEAS Directional CertifiedSpear 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

24

Fixed Cutter BitsStandard PDC Matrix and Steel Bits

M i 6 1 6Cutter Size

Blade Count

i - IDEAS Certified

M/S - Matrix or Steel

Standard PDC Nomenclature

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 premium performance with superior durability.

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

25

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 softer formations, 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 fluid port

Application-tunedimpregnated body material


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, 6

KH813 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 and the highest ROP.

K H 8 1 3Cutter Size

Blade Count

Hybrid

Kinetic Impreg

KineticNomenclature

26

L Feature Low 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 Feature Replaceable 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 Feature Lo-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 restricting lateral 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

27

H Feature Anti-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 Feature Impregnated 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 Feature TSP 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.


28

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 without the need for tripping.

Y Feature 30-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 Feature 40-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 Feature 50-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.


29

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 Feature Restrictor 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 Feature Extended Gauge Length Feature: Longer gauge than standard.Advantage: Enhances bit stability and allows more area for gauge

protection components.Benefit: Improved hole quality.


30

S Feature Short Gauge LengthFeature: Short gauge lengthAdvantage: 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 Feature Active GaugeFeature: Active gauge.Advantage: More aggressive side-cutting.Benefit: Useful for openhole sidetrack applications.

B Feature Backreaming 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.


31

T Feature Turbine 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 without the need for tripping.

PXX Feature Full 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 Feature Diamond-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.


32

D Feature DOG Drilling on Gauge SleeveFeature: DOG* drilling on gauge sleeveAdvantage: Reduces hole spiraling.Benefit: Enhances BHA stability and helps maintain an in-

gauge wellbore.

C Feature Connection Not API StandardFeature: Nonstandard bit connectionAdvantage: 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 Feature IF 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.


33

Product Line Prefix Description

Di IDEAS certified directional design

A 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 LIVE

PR 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 (

35

Roller Cone Products

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

37

Roller Cone BitsGemini Dynamic Twin-Seal Drill Bit

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

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 seals create a synergy that allows them to

17 1/2-in Gi03

G F i 3 5Cutting structure

i - IDEAS certified

Gemini Designation

Gemini Nomenclature

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 bearing failure.

38

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 challengingapplications 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

Shamal Nomenclature

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 GS10

16 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 tungsten carbide inserts.

39

Roller Cone BitsXplorer Premium Slim Hole TCI Bit

Xplorer drill bits provide consistently superior performance in applications ranging from very soft 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 sealsTo handle the high rotation speeds typically seen in the formations in which 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

Xplorer Designation

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.

40

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

X R +

XX - Premium Milled Tooth Cutting Structure

Xplorer Nomenclature

Xplorer Designation

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+ ODVECXR+, 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

41

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 Milled Tooth Cutting Structure

Xplorer - Kaldera

Designation

G F K 47XX - Premium TCI Cutting Structure

Gemini - Kaldera

Designation

TCI

42

Roller Cone Bits FH Single-Seal TCI Drill Bit

FH TCI roller cone drill bits offer superior performance in a wide variety of applications at a lower 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

XX - Cutting Structure

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

43

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 Milled Tooth 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

44

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 and integrates 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, OFM6 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 HHeel Inserts

Medium to Hard Formation Type

Bearing Prefix

8 3/4-in F12

Standard Nomenclature/TCI Insert Bits

F 1 2XX - Cutting Structure

Bearing Prefix

www.slb.com/rockbits

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D Feature Diamond-Enhanced Gauge Row Inserts InsertsFeature: Diamond-enhanced gauge inserts.Advantage: Significantly lower gauge-row wear and breakage

rates, and greater wear-resistance in highly abrasive applications.

Benefit: High-quality, full-gauge wellbore over significantly longer intervals compared with tungsten carbide gauge inserts.

TD Feature Diamond-Enhanced TrucutGauge 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 Feature Shaped 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 Feature Diamond-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 Trucut Gauge 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 Feature Diamond-Enhanced Heel Row 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 Feature All Heel Row Inserts Diamond EnhancedFeature: 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 Feature 100% Diamond-Enhanced Cutting StructureFeature: 100% diamond-enhanced cutting structure.Advantage: Premium cutting structure for drilling very abrasive

formations efficiently, with longer runs and lower weightonbit(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

onbit(WOB).

V Feature V-Flo Nozzle ConfigurationFeature: V-Flo* vectored-flow nozzle configurationAdvantage: 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 Feature Center 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 Feature Lug-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 Feature Semiround-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 Feature Semiround-Top (SRT) TCI Leg Back ProtectionFeature: 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 Feature Diamond-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/SealIdentifier & ProductLine Prefix Applies To Refers To Description

D All Bearing/Seal Nonsealed (open) bearingS All Bearing/Seal Single seal, sealed roller bearingF All Bearing/Seal Single seal, sealed friction bearingMF All Bearing/Seal Single seal, friction bearing motor bitM All Bearing/Seal Single seal, roller bearing motor bitK All Bearing/Seal High temperature seals (geothermal applications)G All Product Line Gemini* bit, twin seal, roller bearingGF All Product Line Gemini bit, twin seal, friction bearingXR 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 bearingS 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 structureDS MT Cutting Structure Soft type (IADC 1-1-X) - applicable to FDS bits onlyDG MT Cutting Structure Medium type (IADC 1-3-X) - does not apply to Gemini bitsS MT Cutting Structure Soft type (formerly DS) - D and G products onlyT MT Cutting Structure Medium soft type (formerly DT)G MT Cutting Structure Medium type (formerly DG) - D and G products onlyV MT Cutting Structure Medium hard type (formerly V2)S MT Cutting Structure Premium self-sharpening with hardfacing materialH MT Carbide Gauge Nonpremium bit - heel insertsB TCI Carbide Gauge Binary carbide gaugeH 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 CuttingStructure SofterthanstandardinsertgradesY TCI Cutting Structure Conical insert A All Cutting Structure Air application bitN All Size Nominal gauge diameterFeature 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 insertsSD1 TCI Diamond Gauge Shaped diamond-enhanced gauge inserts and 51% to 100% heel insertsD TCI Diamond Gauge Semiround top (SRT) diamond-enhanced gauge insertsOD All Diamond Heel 20% to 50% diamond-enhanced heel row insertsOD1 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 protectionQ All Hydraulics Q-Tube hydraulicsV All Hydraulics V-Flo vectored-flow nozzle configurationE All Hydraulics Extended nozzle tubesVE All Hydraulics Vectored extended nozzle tubesJ3 All Hydraulics Dome jets (3 jets in the bit dome)C All Hydraulics Center jetL All Leg Protection Lug pads with tungsten carbide insertsLD All Leg Protection Lug pads with diamond-enhanced insertsR All Leg Protection Upper legback semiround top (SRT) TCI cluster and PS featureRD All Leg Protection Upper legback semiround top (SRT) DEI cluster and PD featurePS All Leg Protection Semiround top (SRT) tungsten carbide leg protectionPD All Leg Protection Semiround top (SRT) diamond-enhanced leg protectionP All LegProtection ModifiedPSfeaturepattern;Note:WestTexasbitsonly

Roller Cone BitsNomenclature

53

Percussion Hammers and Bits

54

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. Whenwaterincursionforcesthosebitstobetrippedoutofthewell,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 bit head retention.

2. The Impax bit retainer is a sleeve trapped between the shoulders of the driver sub and the hammers case. The retainer catches the bit head when a shank (fracture in the spline area) prevents the retention rings from functioning.

3. The secondary catch mechanism is a rope thread, which is machinedontheretainerIDandbitOD.Whentrippingout,rotating the drillstring to the right virtually eliminates any chance that the bit head will come out of the retainer.

1

2

3

www.slb.com/impax

55

www.slb.com/impax

Superior reliability, durability, and performance in hard formations.

Hammer BitsImpax Diamond-Enhanced Insert Hammer Bit

Impax diamond-enhanced insert (DEI) hammer bits feature a hardened steel guide sleeve instead of the conventional blow tube, optimizing energy transfer between the piston and the bit. Replacing the plastic blow tube increases reliability by eliminating failures due to high temperature, erosion, shock and vibration, and abrasive wear.

The large lower chamber increases performance in the high backpressure conditions created by deep-hole drilling, high circulation volumes, and misting and influx. Impax hammers can handle 10%-20% more water volume from mist or influx than conventional hammers, saving a trip when water incursion would cause a conventional hammer to be tripped out of the well.

Dual retention systemWhenencounteringhardrockformationsthatrequiretheuseofapercussion hammer, Impax bits offer a highly reliable retention system that prevents the loss of the bit head in the hole and saves the cost of fishing or sidetracking.

The systems primary retention mechanism is a set of split retaining rings at the top of the bit. The bit retainer is a sleeve that is trapped between the shoulders of the driver sub and the hammer case. It catches the bit head in the event that a shank (fracture in the spline area) prevents the primary retention rings from functioning.

The secondary catch mechanism is a rope thread machined on the retainer ID and on the bit OD. During the trip out of the hole, right-hand rotation of the drillstring virtually eliminates any chance of the bit head coming out of the retainer. For conventional hammer bits, split rings are the only means of attachment to the drillstring, and the possibility of losing the bit head is so great that the bits have built-in fishing threads to facilitate retrieval.

086 H 15 12 DDiamond Enhanced Insert

Number adjacent to Gauge Inserts

Number of Gauge Inserts

H Hammer Bit Indicator

Diameter, x/8 in

Impax Nomenclature 8 3/4-in H1512D

Increased footage at lower costImpax hammer bits have tough and durable DEIs that increase the footage drilled and lower the cost per foot. These bits eliminate the need for reaming, extending the life of the subsequent bit and providing a quality borehole for running casing. In addition, three exhaust ports improve bit-face cleaning for longer life and better ROP. The bit can be supplied with a concave bottom, which optimizes directional control.

DIGR diamond in gauge row hammer bitsDIGR* hammer bits are the cost-effective choice for drilling applications that do not require cutting structures with 100% DEIs. They offer a full range of options for cutting structure layout, but use DEIs only in the gauge row, providing excellent ROP and durability in less demanding formations. DIGR bits use the same retention system as Impax bits.

56

Hammer BitsNomenclature and Optional Features

Impax Nomenclature and Features

Size, 1/8 in Type Available Features

61 H0806 X,6,R,D,PD

62 H1006 X,6,R,D,G

63 H1006 X,6,R,D,G

64 H1006 X,6,R,D,G

66 H1006 X,6,R,D,G

77 H1209 V,7,R,D,PD

83 H1209 V,7,R,D,PD

84 H1209 V,7,R,D,PD

86 H1206 V,7,R,D,PD

86 H1209 V,7,R,D,PD

87 H1209 V,7,R,D,G,PD

87 H1512 V,6,R,D,G,PD

94 H1509 V,7,R,D,PD

95 H1509 V,7,R,C,D,PD

96 H1509 V,7,R,C,D,PD

97 H1509 V,7,R,C,D,PD

105 H1509 V,7,R,D,PD

110 H1209 V,7,R,D,PD

122 H1209 V,7,R,D,G,PD

123 H1209 V,7,R,D,G,PD

146 H1812 V,7,R,D,G,PD

174 H1809 V,7,R,D,G,PD

Impax Features

C Carbide Insert

D Diamond Enhanced Insert (DEI)

F Flat Profile

G Diamond on Gauge

M Modified Profile

N Nonretainable

PD Optional Gauge Protection

R Retainable

T Retainable V Thread

V Concave Profile

X Convex Profile

6 6/8-in [18-mm] Diameter DEI

7 7/8-in [22-mm] Diameter DEI

www.slb.com/impax

6 3/8-in H1006DX6RPD

57

Hammer BitsNomenclature and Optional Features

Gauge InsertsG Feature Diamond (DEI) in Gauge Row

Feature: A cutting structure with carbide face inserts and DEI gauge inserts

Advantage: Exceptional gauge durability and abrasion resistance

Benefit: Excellent bit gauge life when drilling long, medium-soft formation intervals

Bit Head RetentionN Feature Nonretainable

Feature: No retaining feature on the bit head (standard fishing threads)

Advantage: Compatibility with third party hammers that have no bit retention features

Benefit: Flexibility to use the bit in various BHA assemblies such as those used for water wells, construction, etc.

R Feature RetainableFeature: Patented bit head retention systemAdvantage: Prevents loss of the bit head in the holeBenefit: Saves the cost of sidetracking or fishing

T Feature Retainable V ThreadFeature: Slightly modified patented bit headAdvantage: Allows bits with larger diameter shanks to be

run with our patented retention system Benefit: Saves the cost of sidetracking or fishing

Gauge ReinforcementPD Feature Optional Gauge Protection

Feature: All diamond gauge reinforcementAdvantage: Significantly extends the life of the bit gaugeBenefit: Eliminates the need for reaming (the practice of

reducing the hole size after pulling out a nonPD hammer bit), increasing the life of the subsequent bit and providing a quality hole for running casing

Face InsertsC Feature Carbide Insert

Feature: All carbide cutting structureAdvantage: Excellent durability and abrasion resistanceBenefit: Superior and cost-effective drilling performance

in soft to medium-soft formations

D Feature Diamond-Enhanced Insert (DEI)Feature: All DEI cutting structureAdvantage: Exceptional durability and abrasion resistanceBenefit: Excellent drilling performance in longer intervals

through hard formations

6 Feature 6/8-in [18 mm] Diameter DEIFeature: 6/8-in diameter DEI gauge cutting structureAdvantage: Allows use of heavy-set diamond gauge

cutting structuresBenefit: Eliminates the need for reaming, increasing the

life of the subsequent bit and providing a quality hole for running casing

7 Feature 7/8-in [22 mm] Diameter DEIFeature: 7/8-in diameter DEI gauge cutting structureAdvantage: Allows use of diamond gauge cutting

structures with improved impact-damage resistanceBenefit: Eliminates the need for reaming, increasing the

life of the subsequent bit and providing a quality hole for running casing

Bit Profile ShapesF Feature Flat

Feature: Flat bottom with a single gauge-angle bit head profile

Advantage: Allows use of heavier-set cutting structures on the bit face

Benefit: Excellent drilling performance in hard formation intervals

M Feature ModifiedFeature: Nonstan

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