Bits Catalog

2012 Product Catalog

Headquarters 1310 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.

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

Technological Expertise

1

Technological Expertise Innovative Smith Bits technology provides analyses, optimization, and support for every stage of the drilling program, from planning to execution 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)

2

Engineering and Modeling IDEAS – Integrated Drillbit Design Platform

Delivering application-specific drill bits with higher performance and greater reliability The IDEAS* platform uses advanced simulation and modeling to design and certify every new Smith Bits drill bit. It has five basic elements that enable it to optimize bit performance.

Comprehensive drilling system analysis The 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 interaction between individual elements of the drilling assembly.

Holistic design process Smith 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 enhancements Continuous improvement results in bits for a specific application that consistently outperform 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 results By 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-anderror approach is replaced by laboratory tests and simulations to quantify variables such as cutter forces and rock removal rates.

Integration of advanced materials Stronger 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 impactresistant cutters, and an optimal design for high performance.

The IDEAS Platform

Define Performance Objectives

IDEAS Simulation ■■Design ■■Test ■■Analyze

Build Bit Test Bit Certify Bit Integrate new bit into product line

IDEAS platform eliminates the costly and timeconsuming trial-and-error methods of the traditional drillbit design process, enabling Smith Bits to deliver a better solution faster.

www.slb.com/IDEAS 3

Engineering and Modeling IDEAS Certification for Directional Applications

Improving performance, reduces risk, and keeps directional wells and drilling budgets on target 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 incorporated into conventional directional bits merely allows an intrinsically unstable bit design to drill acceptably for a specific application. If the bit is subsequently used with a slightly different BHA or in a different application, it becomes unstable and a new or significantly modified bit is required. Bits for directional drilling that have IDEAS certification remain stable and provide superior performance with different types of steering systems in a wide range of applications. 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.

www.slb.com/IDEAS 4

Engineering and Modeling Computational Fluid Dynamics (CFD) Analysis

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 configurations in order to optimize flow patterns for cuttings removal. Ensuring the cutting structure 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.

5

Engineering and Modeling i-DRILL Engineered Drilling System Design

Maximize performance with a dynamically stable drilling assembly. i-DRILL* engineered drilling system design uses predictive modeling to identify solutions 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 component of the BHA and the drillstring. They evaluate a range of options to reduce harmful vibrations, thus increasing equipment life, minimizing failures, increasing ROP, improving hole condition and directional 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-error Employing 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 laboratory 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 performance through formation transitions. Virtual testing of new technology and unconventional approaches eliminates the risk and expense of trial-and-error on the rig.

Integration of data from diverse sources improves accuracy Using offset well data, surface and downhole measurements, and a thorough knowledge of products and applications, the

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 performance without risking lost rig time associated with exceeding the limit or inefficiencies 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 directional BHAs in space and time. • Identify weak areas in the drillstring and BHA 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-diameter BHA stability. • Develop improved drilling program schedules with reduced risk of unplanned delays.

• 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

i-DRILL analyses The 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 conditions • bit durability and ROP through different formations.

www.slb.com/idrill 6

Engineering and Modeling Advanced Services Engineering (ASE) In-house bit recommendations and operational advice The ASE team has an established track record of lowering drilling costs through improved performance, by recommending the ideal bit for the application—a vital aspect of a comprehensive well plan. Bit recommendations and operational advice are based upon the technologies and operating parameters best suited for a particular application.

Expert drillbit selection The ASE group provides an experienced bit application specialist for the client’s drilling team, to deliver engineered bit recommendations and advice to both the operator and the service providers on the day-to-day requirements for maaintaining superior bit performance. 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 combination of cutting structure, gauge protection, hydraulic configuration, and other bit optimizing features • YieldPoint RT* drilling-hydraulics and hole-cleaning simulation program for jet nozzle optimization.

Optimized drilling plan The 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 reconstruction of expected lithologies (gleaned from well logs from the closest offset wells),

a formation analysis, rock strength analysis, and both roller cone and fixed cutter bit selections. The YieldPoint RT program creates a graphical 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 questions about hole cleaning, with data from the formations to be encountered. Using a cuttings transport model, the program can help assess potential hole-cleaning difficulties 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.

7

Continuous evaluation while drilling To establish measurable goals, the ASE engineer prepares a comprehensive plan. During drilling, performance is evaluated continuously against this plan. Upon completion of the well, a postwell analysis measures the success of the plan and provides a permanent 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 investigated, and decisions are made to correct the issues, subject to the objective of maintaining peak drilling efficiency and safety.

www.slb.com/ase

Engineering and Modeling Advanced Services Engineering (ASE) Post Well Analysis A 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.

www.slb.com/ase 8

Engineering and Modeling DBOS 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 evaluation process 1. 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 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.

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

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.

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 9

Engineering and Modeling DBOS 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.

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 applications

Neural networks, planned run simulation and real-time optimization Neural networks have been used in DBOS for synthetic log generation 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

Optimized 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.

www.slb.com/dbos 10

Engineering and Modeling

YieldPoint 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 assessment YieldPoint 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 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 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 11

Engineering and Modeling DRS 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 continuously added for oil, gas, and geothermal wells. With this detailed data and the capabilities 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 12

PDC Technology ONYX II Premium PDC Cutters

ONYX II cutters have established a new benchmark for performance in the toughest drilling applications New technology increases performance When 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 significantly improved overall PDC bit performance while reducing drilling costs.

Comprehensive laboratory evaluation A 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

ONYX

research and development engineers evaluated the new generation ONYX II cutter to measure it against the original ONYX shearing element. In a controlled laboratory comparison, ONYX II cut 20% more footage and maintained a significantly better dull condition 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.

ONYX II

Cutter technology has evolved over the years to enhance the performance 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 generations of PDC cutters. (above cutters shown after standard granite abrasion test)

Resistance to Abrasion

Extended granite abrasion test

First generation Second generation premium PDC cutters premium PDC cutters 2003 2006

13

ONYX 2009

ONYX II 2011

www.slb.com/onyxII

Roller Cone Technology Adaptive Hydraulics System

Because of the wide range of drilling applications for roller cone bits, no single hydraulics configuration is optimal for every situation. Different applications require each of the three primary functions of bit hydraulics—cutting-structure cleaning, bottomhole cleaning, and cuttings evacuation—to varying degrees. With the Flex-Flo* adaptive hydraulics system, Smith Bits offers the ideal configuration for each application 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.

S-Flo In applications with high percentages of solids in the mud and in abrasive formations, S-Flo* standard-flow nozzle configuration uses three identical nozzles to allocate hydraulic energy for increased bit life.

Hydraulic Function vs. Formation Zone 4

Hydraulic Function Need

To help select the most suitable bit hydraulics system, typical applications have been divided into four categories or zones determined by formation types, ranging from very soft to very hard. Within each zone, the relative 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.

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 bottomhole cleaning.

Zone 3

Zone 2 Zone 1 Very soft and/or sticky formations that generate very large volumes of cuttings with Milled Tooth bits and very soft TCI bits.

14

Low strength formations that generate large cuttings volumes and drill with soft TCI bits.

Medium strength formations that generate moderate cuttings volumes with mediumhard TCI bits.

Soft/StickyHard/Abrasive

High strength formations that generate low cuttings volumes with hard TCI bits.

Cutting Structure Cleaning Bottom-Hole Cleaning Cuttings Evacuation

Roller Cone Technology Typhoon Hydraulics

Superior Hole Cleaning for Large OD Boreholes 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.

VE nozzles direct the fluid flow with precision to the leading edge of the cones, while the J3 nozzles direct flow towards the intermesh area between the cones. The combined effect of these six, precisely oriented nozzles is a flow pattern that significantly improves cone cleaning, optimizes the displacement of cuttings from the bottom of the hole up the drillstring, and maximizes ROP.

CFD analysis allows Smith Bits engineers to optimize available hydraulic energy for maximium ROP.

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.

www.slb.com/shamal 15

Roller Cone Technology Inserts

Insert Options A 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, enhancements 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, 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 formations 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.

Incisor DogBone

Coarse Carbide Microstructure

Material Choices Insert material grades are not specific to a particular design. Materials can be optimized for individual applications to maximize performance, 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 challenging applications. Diamond inserts can be used in the heel row, the gauge row, and on the bit leg.

Diamond-Enhanced Insert

16

ACE

Relieved Gauge Chisel Chisel

Conical

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 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 formation 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 material wear rates.

Smith Bits GHIs are more durable than conventional GHIs, and will drill faster for a longer period of time.

17

Fixed Cutter Products

19

Fixed Cutter Bits Product Line 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

20

Fixed Cutter Bits Directional PDC Drill Bit

IDEAS certification for directional bits ensures excellent steering response and improved performance 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 timeconsuming and costly trips due to vibration and shocks is greatly reduced.

Type

Size Availability, in

Type

Size Availability, in

SDi613

17 1/2

SD519

16, 17 1/4

SDi616

13 1/2

MD519

8 1/2, 12 1/4

MDi416

6 1/8

MD611

5 7/8

MDi513

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

MD613

6, 6 1/8

MDi516

6 1 /8, 8 1/2

MD616

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

MDi519

8 3/4, 14

MD619

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

MDi613

6 3/4, 8 5/8, 8 1/2, 9 1/2, 9 7/8

MD813

8 1/2

MDi616

8 1/2, 14 3/4

MDi619

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

MD816

6, 6 1/8, 8 1/2, 9 1/2, 12 1/4, 16 1/2

MDi713

5 7/8

MD819

12 1/4

MDi716

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

MD913

8 1/2, 12 1/4

MDi719

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

MD916

8 1/2, 12 1/4

MDi813

5 3/4, 8 3/4, 12 1/4, 14 1/2, 14 3/4, 16 1/2

MD919

12 1/4, 13 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

Directional Nomenclature

MDi616 Cutter Size

Blade Count i - IDEAS Certified

D - IDEAS Directional Certified M/S - Matrix or Steel

www.slb.com/directional 21

Fixed Cutter Bits

SHARC High-Abrasion-Resistance PDC Drill Bit Bit durability and maximum ROP in abrasive formations 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.

Type

Size Availability, in

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

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.

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

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 performance in challenging applications all over the world.

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

The key to achieving both bit durability and maximum ROP is maintaining 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.

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

SHARC Nomenclature

MDSi619 Cutter Size

Blade Count i - IDEAS Certified

S - SHARC D - IDEAS Directional Certified M/S - Matrix or Steel

www.slb.com/sharc 22

Fixed Cutter Bits

Spear 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.

Type

Size Availability, in

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

Efficient cuttings removal

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

Spear 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.

Spear bits feature a bullet-shaped body profile that makes it easier for cuttings to sweep around the body and into the junk slot

Spear Nomenclature

SDi613 Cutter Size

Blade Count i - IDEAS Certified D - IDEAS Directional Certified Spear Shale-Optimized Steel-Body

www.slb.com/spear 23

Fixed Cutter Bits

Standard PDC Matrix and Steel Bits The workhorse of the oilfield, delivering premium performance with superior durability.

Type

Size Availability, in

Type

Size Availability, in

Mi413

6 1/2

S619

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

Mi416

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

S716

14 3/4

Mi419

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

S719

12 1/4

Mi513

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

S816

16, 17 1/2, 26

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.

Mi516

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

S819

26

Mi519

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

Si419

8 1/2

Mi613

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

Si519

8 1/2, 12 1/4

Mi616

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

Si613

16

Mi619

12 1/4, 17

Si616

12 1/4

Mi713

6 1/8

Si619

13 1/2

Mi716

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

Si819

23, 24

Mi811

6

M413

7 7/8

Mi813

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

M416

6, 7 7/8

Mi816

12 1/4, 17 1/2

M419

8 1/2

Mi913

7 7/8, 12 1/4

M509

3 3/4

Cutter Size

Mi916

12 1/4, 14, 16

M511

4 1/2

Blade Count

Mi919

16

M513

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

i - IDEAS Certified

Mi1016

12 1/4

M516

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

M/S - Matrix or Steel

S416

6 3/4

M519

6, 9 7/8, 12 1/4

S422

6,12 1/4

M609

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

S516

8 1/2,12 1/4

M613

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

S519

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

M616

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

Standard PDC Nomenclature

M i 616

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

M619

7 7/8, 17 1/2

S522

12 1/4

M711

5 7/8

S613

16

M713

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

S616

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

M716

6, 8 3/8, 12 1/4

M809

6, 6 1/8, 6 3/4

M813

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

M816

16

M909

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

M916

8 1/2

M1609

8 1/2, 8 3/4

8 1/2-in Mi616

www.slb.com/pdc 24

Fixed Cutter Bits

Kinetic Diamond-Impregnated Bit for High-Speed Applications Kinetic bits have established world and numerous field records for the most footage drilled and the highest ROP. 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.

Type

Size Availability, in

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

Application-specific design

K707

8 1/2, 14 3/4

Most 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.

KH613

5 7/8, 6

KH813

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

Open face for optimum clearing

Brazed--in GHI

Cast-in GHI

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.

Dedicated fluid port

Central flow

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.

Application-tuned impregnated body material

High performance with turbodrills Because 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.

Kinetic Nomenclature

KH813

Cutter Size Blade Count Hybrid

www.slb.com/kinetic

Kinetic Impreg

25

Fixed Cutter Bits Optional Features

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 Inserts Feature:

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 Option Feature: Lo-Vibe depth of cut control insert. Advantage: In applications in which bit whirl is a problem, the LoVibe 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.

26

Fixed Cutter Bits Optional Features

Z Feature TSP Diamonds on Leading Edge Feature: Advantage: Benefit:

Thermally stable polycrystalline (TSP) diamonds are placed on the leading edge of each blade. Enhances durability in specific locations on the bit profile. Increases wear resistance, ensures full-gauge hole, and extends bit life.

K Feature Impregnated Cutter Backing Feature:

Diamonds impregnated in the matrix behind the PDC cutters. Advantage: Limits the progress of PDC cutter wear. Benefit: Increased footage drilled in abrasive applications.

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.

27

Fixed Cutter Bits Optional Features

N Feature Fewer Nozzles than Standard Feature: 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 Nozzles Feature: 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 Nozzles Feature: 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 Nozzles Feature: 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.

28

Fixed Cutter Bits Optional Features

Q Feature Fixed Ports Feature: 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 Pin Feature:

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.

29

Fixed Cutter Bits Optional Features S Feature Short Gauge Length Feature: 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 Feature Active Gauge Feature: Active gauge. Advantage: More aggressive side-cutting. Benefit: Useful for openhole sidetrack applications.

B Feature Backreaming Cutters Feature: 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.

30

Fixed Cutter Bits Optional Features

PX Feature Diamond-Enhanced Gauge Protection Feature: 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.

T Feature Turbine Sleeve Feature: 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 Sleeve Feature: 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.

31

Fixed Cutter Bits Optional Features

D Feature DOG Drilling on Gauge Sleeve Feature: DOG* drilling on gauge sleeve Advantage: Reduces hole spiraling. Benefit: Enhances BHA stability and helps maintain an ingauge wellbore.

C Feature Connection Not API Standard Feature: 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 Feature IF Connection Feature: 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.

32

Fixed Cutter Bits Nomenclature 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 (