Bits Catalog

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(1)Product Catalog.

(2) Headquarters 1310 Rankin Rd. Houston, TX 77073-4802 www.slb.com Copyright © 2013 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. 13-BT-0039 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..

(3) Table of Contents Technological Expertise. 1–19. Innovative Smith Bits technology for every stage of drilling. Fixed Cutter Bits. 21–33. A wide range of PDC and diamond-impregnated bits. Roller Cone Bits. 37–54. A comprehensive selection for various applications. Percussion Hammers and Bits. 55–59. Impax hammer products designed for oilfield applications. Specialty Products. 61–67. Reference Guide. 69–90.

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(5) Technological Expertise. 1.

(6) 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. Fixed Cutter Technology ■■. Stinger* Conical diamond element. ■■. ONYX 360* Rolling PDC cutter. Roller Cone Technology ■■. Hydraulics. ■■. Inserts. Diamond-Impregnation Technology ■■. Grit Hot-Pressed Inserts (GHIs). 2.

(7) Engineering and Modeling IDEAS Integrated Drillbit Design Platform. Delivering application-specific drill bits with higher performance and greater reliability The IDEAS* design 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 trialand-error approach is replaced by laboratory tests and simulations to quantify variables such as cutter forces and rock removal rates.. Advanced material integration. 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 Platform Simulation ■■ Design ■■. Test. ■■. Analyze. Build Bit. Test Bit. Certify Bit Integrate new bit into product line. IDEAS platform eliminates the costly and time-consuming trial-and-error methods of the traditional drillbit design process, enabling Smith Bits to deliver a better solution faster.. www.slb.com/IDEAS 3.

(8) Engineering and Modeling. IDEAS Design Platform 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.

(9) 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 design modifications affect bit performance and choose the optimum solution.. 5.

(10) 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 The i-DRILL drilling system design enables quantification of vibrations and ROP produced by a virtual drilling system as a function of time. This is accomplished by combining a bit-drilling-rock model 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.. ■■. 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. 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 dualdiameter BHA stability. Develop improved drilling program schedules with reduced risk of unplanned delays.. i-DRILL design analyses ■■. ■■. ■■. 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.

(11) 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.. 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 7.

(12) Engineering and Modeling Advanced Services Engineering (ASE). Postwell 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.

(13) Engineering and Modeling DBOS Drillbit Optimization System. DBOS system evaluation process. 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.. 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.

(14) 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.. Neural networks, planned run simulation and real-time optimization. Neural networks have been used in DBOS system for synthetic log generation since 1997, and serves as the principal modeling for on-time, real- time DBOS 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 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 grade) in run simulation. In predrilling simulation, drilling systems can be tested in advance to find the most efficient way to drill.. Real-time applications. 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 system has contributed to improvements in bit run performance on the order of 20 to 40% or better in ROP, longer bit life, reduced incidents of drillbit related failures.. www.slb.com/DBOS 10.

(15) 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 realtime solution that substantiall y reduces costs.. www.slb.com/YieldPointRT 11.

(16) 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.

(17) Stinger. Conical diamond element Beyond shear performance The Stinger* conical diamond element provides an innovative cutting structure enhancement that significantly increases a PDC bit’s performance. Located at the bit’s center, the element enables high-point loading to fracture rock more efficiently for increased durability and ROP across a wide range of formations and operating parameters. In field tests comparing conventional PDC bits and PDC bits fitted with a Stinger element across a wide range of rock types and operating parameters, bits with a Stinger element demonstrated greater durability and stability while increasing ROP as much as 46%.. Borehole center challenges conventional PDC bits. By reconfiguring the bit with the Stinger element, a column of rock is allowed to form at the center of the cutting structure, which is continuously crushed and fractured, increasing drilling efficiency.. Because the rotational velocity of cutters decreases with their proximity to the center of a bit’s cutting structure, rock removal by the center-most cutters of conventional PDC bits is much less efficient, especially in hard formations. And since the center cutters bear the highest load, operational and formation changes can cause large variations in depth of cut, inducing bit torque fluctuations.. Stinger element increases PDC bit drilling efficiency To decrease PDC bit damage and increase performance at the center of the cutting structure, bit design engineers selectively removed the PDC bit’s center-most cutters to position the Stinger element. The absence of these cutters allows a stress-relieved column of rock to develop that is continuously crushed and fractured by the Stinger element, improving drilling efficiency.. The Stinger element combines a unique conical geometry with synthetic diamond material that is engineered to provide impact strength and superior resistance to abrasive wear.. Stinger nomenclature. M S i Z 6 19 Cutter size Blade count Z – Stinger—conical diamond element i – IDEAS certified S – SHARC M/S – Matrix or steel. www.slb.com/Stinger 13.

(18) ONYX 360 Rolling PDC cutter. The next revolution in PDC cutter durability The ONYX 360* rolling PDC cutter substantially increases PDC bit durability by revolving 360°. Strategically positioned in the highest wear areas of a bit’s cutting structure, the rolling cutter’s entire diamond edge is used to shear the formation.. Fixed cutter limits diamond edge contact Because most of its cutting edge is fixed into the bit blade, very little of a fixed cutter’s edge contacts the formation. Accordingly, more than 60% of the cutter’s circumferential edge is unused during a bit run. The ONYX 360 cutter’s rotating action allows the diamond edge to stay sharper longer, extending cutter life far beyond that of premium fixed cutters. When compared with fixed-cutter-only bits, PDC bits that included ONYX 360 rolling cutters demonstrated run length increases of up to 57%.. The ONYX 360 cutter’s shaft is fully contained within an integrated housing to ensure continuous rotation and cutter retention during drilling.. Inventive design increases cutter life To integrate a rolling cutter into a PDC bit’s cutting structure would require a novel and robust design. Smith Bits R&D engineers developed a cutter system composed of a housing that is brazed into the bit blade, and within which a sleeve encloses and completely secures the cutter while allowing it to rotate. The rolling cutter’s orientation in the bit blade relative to its contact with the formation, coupled with the bit’s drilling force, drives efficient rotation of the cutter. This reduces wear for more sustained rates of penetration and fewer bit replacement trips.. ONYX 360 nomenclature. M S i R 6 19 Cutter size Blade count R – ONYX 360 rolling cutter i – IDEAS certified S – SHARC M/S – Matrix or steel. www.slb.com/ONYX360 14.

(19) ONYX 360 Rolling PDC cutter. Comprehensive evaluation validates rolling concept. Premium fixed cutter. 90. The wear that fixed cutters incur is concentrated on only a small percentage of the cutter’s entire diamond edge. As a result, after 90 passes on a test formation, premium fixed cutters developed extreme wear flats. Because 100% of the ONYX 360 rolling cutter’s diamond edge engaged the test formation, wear was evenly distributed, resulting in virtually no wear after 300 passes and very little wear after 540 passes.. ONYX 360 cutter. 120. 0. 50. 300. 100. 150. 200. 250. 480. 300. 350. 400. 540. 450. 500. 550. 600. Rock cutting passes. Wear Flat Area After 150 hours. 0.14. Wear Flat Area, in2. 0.12 High wear area. 0.10 0.08 0.06 0.04 0.02 0. 0. 0.5. 1. 1.5. 2. 2.5. 3. 3.5. 0. Distance from bit center, in. 0.5. 1. 1.5. 2. 2.5. 3. 3.5. Distance from bit center, in. ONYX 360 cutters Premium fixed cutters. In abrasive formations, the bit’s shoulder area (between the center of the cutting structure and gauge) is where cutters typically experience the greatest amount of wear. The ability IDEAS drillbit design platform has to predict the degree and precise location of this wear makes it an invaluable design tool.. Based on analysis using IDEAS design platform, ONYX 360 rolling cutters can selectively replace fixed cutters in the highest wear areas of a PDC bit’s cutting structure.. www.slb.com/ONYX360 15.

(20) 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.. 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.. 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. Zone 3. 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. 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.. Low strength formations that generate large cuttings volumes and drill with soft TCI bits.. Medium strength formations that generate moderate cuttings volumes with medium hard TCI bits.. Soft / Sticky Hard /Abrasive. 16. High strength formations that generate low cuttings volumes with hard TCI bits.. Cutting Structure Cleaning Bottom-Hole Cleaning Cuttings Evacuation.

(21) 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. These are available in four options: ■■. ■■. ■■. ■■. Incisor. DogBone. ACE. 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.. 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. 17. Relieved Gauge Chisel. Chisel. Conical.

(22) 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 18.

(23) 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.. 19.

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(25) Fixed Cutter Products. 21.

(26) Fixed Cutter Bits Product Line Directional PDC Drill Bit. Matrix or steel 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. 22.

(27) 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 time-consuming and costly trips due to vibration and shocks is greatly reduced.. Type. Size Availability, in. Type. Size Availability, in. SDi613. 171/2. SD519. 16, 171/4. SDi616. 131/2. MD519. 81/2, 121/4. MDi416. 6 ⁄8. MD611. 57⁄8. MDi513. 5 ⁄8, 6 ⁄8, 61/4, 7 ⁄8, 83/4. MD613. 6, 61⁄8. MDi516. 6 ⁄8, 81/2. MD616. 6, 83⁄8, 97⁄8, 121/4, 143/4. MDi519. 83/4, 14. MD619. 81/2, 91/2, 121/4, 17. 1 5. 1. 7. 1. MDi613. 63/4, 81/2, 8 ⁄8, 91/2, 9 ⁄8. MD813. 81/2. MDi616. 81/2, 143/4. MD816. 6, 61⁄8, 81/2, 91/2, 121/4, 161/2. MDi619. 121/4, 141/2, 16, 171/2. MD819. 121/4. 5. 7. MDi713. 5 ⁄8. MD913. 81/2, 121/4. MDi716. 81/2, 121/4, 143/4. MD916. 81/2, 121/4. MDi719. 81/2, 105⁄8, 121/4, 141/2. MD919. 121/4, 131/2. MDi813. 53/4, 83/4, 121/4, 141/2, 143/4, 161/2. MDi816. 83⁄8, 81/2, 105⁄8, 121/4, 133/4, 171/2, 181⁄8, 181/4. 7. Directional nomenclature. M D i 6 16 Cutter size Blade count i – IDEAS certified D – IDEAS directional certified M/S – Matrix or steel. www.slb.com/directional. 121/4-in MDi616. 23.

(28) 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. Additionally, the double rows are oriented to ensure that hydraulic cleaning and cooling efficiency are maintained. This feature is important not only in abrasive interbedded sands, but also in surface intervals with high ROP or when hydraulic energy is compromised, for example, on motor runs. When drilling hard, highly abrasive formations, SHARC PDC bits maintain maximum ROP over the target interval. Drilling faster and staying downhole longer, these bits are achieving superior performance in challenging applications all over the world. 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.. Type. Size Availability, in. MDSi613. 57⁄8, 6, 61⁄8, 63/4, 77⁄8, 83/4. MDSi616. 77⁄8, 81/2, 83/4, 97⁄8, 12, 121/2, 16, 171/2. MDSi716. 77⁄8, 81/2, 83/4, 97⁄8, 12, 121/2, 16, 171/2. MDSi619. 143/4, 16. MSi416. 61⁄8, 63/4, 77⁄8, 81/2, 83/4. MSi513. 61⁄8, 61/4, 77⁄8. MSi516. 61⁄8, 63/4, 77⁄8, 81/2, 83/4, 97⁄8, 12. MSi519. 77⁄8, 81/2, 83/4, 97⁄8, 121/4. SDSi519. 121/4, 171/2. MSi611. 61⁄8. MSi613. 6, 61⁄8, 61/4, 61/2, 63/4, 77⁄8, 81/2, 83/4, 12. MSi616. 6, 61⁄8, 61/2, 63/4, 77⁄8, 81/4, 81/2, 83/4, 91/2, 97⁄8, 105⁄8, 121/4, 143/4, 16. MSi711. 55⁄8, 57⁄8, 6. MSi716. 77⁄8, 81/2, 83/4, 97⁄8, 12, 121/2, 16, 171/2. MSi816. 77⁄8, 83⁄8, 81/2, 83/4, 97⁄8, 121/4, 16, 171/2. MSi1013. 12. SHARC nomenclature. M D S i 6 13 Cutter size Blade count i – IDEAS certified S – SHARC D – IDEAS directional certified M/S – Matrix or steel. www.slb.com/SHARC. 81/2-in MDSi613LBPX. 24.

(29) Fixed Cutter Bits. Spear Shale-Optimized Steel-Body PDC Drill Bit Design based on proven drilling performance Introduced in 2011, the Spear* shale-optimized steel-body PDC drill bit significantly reduced bit balling and cuttings that tended to pack around the blades of matrix-body bits.. Type. Size Availability, in. SDi513. 6, 61⁄8, 61/4, 61/2, 63/4, 77⁄8, 81/2, 83/4. SDi611. 63/4, 83/4. Characterized by its distinctive bullet shape and smaller diameter steel body, the streamlined Spear bit put more distance between the bit body and borehole. This helped increase cuttings evacuation by minimizing blade packing and nozzle plugging, allowing the bit to drill more efficiently. After more than 5,000 runs, the Spear bit’s innovative capabilities have proven to increase drilling performance and lower drilling costs of curve- and long-lateral sections in unconventional shale plays.. SDi613. 81/2, 83/4. SDi711. 61⁄8, 61/2, 63/4. SDi713. 61⁄8, 63/4, 77⁄8, 81/2, 83/4. Next-generation shale-optimized steel-body PDC drill bits. Based on Spear bit performances, and a redesign program conducted by Smith Bits using IDEAS integrated drillbit design platform, the next-generation Spear shale-optimized PDC bit has demonstrated greater directional control and ROP increases of as much as 40%.. The next-generation Spear bits feature a smaller body profile that promotes the movement of cuttings around the body and into the junk slot.. Spear nomenclature. S D i 6 13 Cutter size Blade count i – IDEAS certified D – IDEAS directional certified S – Spear shale-optimized steel-body. www.slb.com/Spear 25.

(30) Fixed Cutter Bits. Standard PDC Matrix and Steel Bits The workhorse of the oilfield, delivering premium performance with superior durability. 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.. Standard PDC nomenclature. M i 6 16. Type. Size Availability, in. Type. Size Availability, in. Mi413. 61/2. S619. 81/2, 121/4, 171/2. Mi416. 61⁄8, 61/4, 63/4, 75⁄8, 77⁄8. S716. 143/4. Mi419. 6 ⁄8, 81/2, 9 ⁄8. S719. 121/4. Mi513. 61/4, 61/2, 77⁄8, 83/4. S816. 16, 171/2, 26. Mi516. 61/2, 83/4, 121/4. S819. 26. Mi519. 83/4, 97⁄8, 121/4. Si419. 81/2. Mi613. 7. 61/2, 7 ⁄8, 83/4. Si519. 81/2, 121/4. Mi616. 77⁄8, 97⁄8, 121/4. Si613. 16. Mi619. 121/4, 17. Si616. 121/4. 1. 7. Mi713. 6 ⁄8. Si619. 131/2. Cutter size. Mi716. 77⁄8, 83/4, 12, 121/4, 143/4. Si819. 23, 24. Blade count. Mi811. 6. M413. 77⁄8. i – IDEAS certified. Mi813. 61⁄8, 63/4, 105⁄8, 171/2. M416. 6, 77⁄8. M/S – Matrix or steel. Mi816. 121/4, 171/2. M419. 81/2. Mi913. 77⁄8, 121/4. M509. 33/4. Mi916. 121/4, 14, 16. M511. 41/2. Mi919. 16. M513. 43/4, 47⁄8, 61⁄8, 61/4, 77⁄8. Mi1016. 121/4. M516. 57⁄8, 97⁄8, 115⁄8, 121/4, 16. S416. 63/4. M519. 6, 97⁄8, 121/4. S422. 6,121/4. M609. 35⁄8, 33/4, 41⁄8, 41/2, 43/4. S516. 81/2,121/4. M613. 6, 81/2, 115⁄8, 121/4. S519. 81/2, 10 ⁄8, 121/4, 131/2, 143/4, 16, 17, 171/2. M616. 63/4, 97⁄8, 121/4. S522. 121/4. M619. 77⁄8, 171/2. S613. 16. M711. 57⁄8. S616. 81/2, 121/4, 171/2. M713. 81/2, 83/4, 91/2, 121/4. 1. 5. M716. 6, 83⁄8, 121/4. M809. 6, 61⁄8, 63/4. M813. 6, 77⁄8, 9, 121/4. M816. 16. M909. 43/4, 57⁄8, 6, 61/2. M916. 81/2. M1609. 81/2, 83/4. www.slb.com/pdc. 83/4-in Mi616MSPX. 26.

(31) 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. 5–121/4. K505. 33/4, 57⁄8, 6, 61⁄8, 63/4, 81/2, 12, 143/4, 16. K507. 6, 61/2, 83⁄8, 81/2, 83/4, 121/4. K703. 41/2–83/4. K705. 33/4, 6–121/4. Application-specific design. K707. 81/2, 143/4. KH613. 57⁄8, 6. KH813. 83⁄8, 81/2, 91/2, 121/4. 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.. Open face for optimum clearing Brazed-in GHI Application-tuned impregnated body material. 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.. Cast-in GHI. Central flow Dedicated fluid port. A hybrid design, designated with an “H” in the bit nomenclature, is a combination of a traditional PDC bit and a diamondimpregnated bit. Hybrid Kinetic drill bits are suitable in borderline-PDC-drillable formations.. 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. K H 8 13 Cutter size Blade count H – Hybrid K – Kinetic impreg. www.slb.com/Kinetic 27.

(32) Fixed Cutter Bits Optional Features. L Feature Low Exposure (MDOC—Managed Depth Of Cut) Feature: . L. 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 to extend bit life. M Feature Replaceable Lo-Vibe Inserts Feature: . M. 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: . Provides superior ROP and bit life. V Feature Lo-Vibe Option Feature: . V. Lo-Vibe depth of cut control insert. Advantage: In applications that produce bit whirl, 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 to drill long drilling intervals eliminates tripping. 28.

(33) Fixed Cutter Bits Optional Features. Z Feature Stinger—conical diamond element. Z. Feature: . Element fails rock more efficiently than conventional PDC bit cutters. Advantage: Improves bit stability and decreases vibration Benefit:. Increases drilling efficiency for greater ROP. K Feature Impregnated Cutter Backing. k. Feature: . Diamonds impregnated in the matrix behind the PDC cutters. Advantage: Limits PDC cutter wear Benefit: . Increased footage drilled in abrasive applications. H Feature Anti-balling. h. 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: . 29. Superior ROP and bit life; longer drilling intervals eliminates tripping.

(34) Fixed Cutter Bits Optional Features. N Feature Fewer Nozzles than Standard Feature: . N. Fewer nozzles. Advantage: Reduced nozzle count to match drilling, formation, and hydraulic system capabilities; reduces the flow rate required to achieve an appropriate hydraulic horsepower per square inch (HSI); eliminates more numerous, smaller nozzles that can become plugged Benefit: . Superior ROP and bit life; longer drilling intervals eliminates tripping. Y Feature 30-Series Nozzles Feature: . Y. 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 resulting in reduced ROP or bit life. W Feature 40-Series Nozzles Feature: . w. Contains 40-series nozzles. Advantage: Increased thread size for resistance to wear and erosion Benefit: . Reduced pop-up force when tightening nozzle. U Feature 50-Series Nozzles Feature: . u. Contains 50-series nozzles. Advantage: Maximum adjustable total flow area (TFA) for smalleror heavier-set designs Benefit:. High efficiency for cleaning, cooling, and cuttings evacuation without compromising the cutting structure, resulting in reduced ROP or bit life. 30.

(35) Fixed Cutter Bits Optional Features. Q Feature Fixed Ports. q. Feature: . Incorporates fixed ports. Advantage: Optimizes hydraulics in applications where nozzles compromise bit design because of space limitations or other similar reasons; provides additional cleaning of the cutting structure Benefit:. Improves ROP and bit life. R Feature ONYX 360 rolling cutter. r. Feature: . Cutters revolve 360° to stay sharper longer. Advantage: Increases run footage Benefit: . Extends bit durability. E Feature Extended Gauge Length. e. Feature: . Longer than standard gauge. Advantage: Enhances bit stability and allows more area for gauge protection components Benefit:. 31. Improves borehole quality.

(36) Fixed Cutter Bits Optional Features S Feature Short Gauge Length Feature: . s. Short gauge length. Advantage: Reduced bit height improves bit steerability for directional and horizontal applications; 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:. a. Active gauge. Advantage: More aggressive side cutting Benefit:. Aids openhole sidetrack applications. B Feature Backreaming Cutters Feature: . b. Backreaming cutters. Advantage: Strategic placement of cutters on upside of each blade to allow backreaming in tight spots; reduces potential of “bit sticking” while pulling out of the hole Benefit: . Allows a degree of backreaming sufficient to condition borehole without major risk of gauge pad wear. 32.

(37) Fixed Cutter Bits Optional Features. PX Feature Diamond-Enhanced Gauge Protection. px. Feature: . Diamond-enhanced gauge protection. Advantage: Thermally stable polycrystalline (TSP) diamonds provide extra protection to gauge. Benefit: . In-gauge borehole and longer bit life; longer drilling intervals eliminates tripping. T Feature Turbine Sleeve. t. Feature: . Turbine sleeve. Advantage: Reduces vibration and borehole spiraling in turbine applications; sleeve lengths can be varied to best match a specific application Benefit: . Improved ROP and bit life; long drilling intervals eliminates tripping. PXX Feature Full-Diamond Gauge Pad on Turbine Sleeve. pxx. Feature: . Full-diamond gauge pad on turbine sleeve. Advantage: Diamond-enhanced inserts provide greatest possible extend gauge life in highly abrasive formations and underbalanced drilling Benefit: . 33. Produces in-gauge borehole in extreme drilling environments; longer drilling intervals eliminates tripping.

(38) Fixed Cutter Bits Optional Features. D Feature DOG Drilling on Gauge Sleeve Feature: . d. DOG* drilling on gauge sleeve. Advantage: Reduces borehole spiraling Benefit: . Enhances BHA stability and helps maintain in‑gauge wellbore. C Feature Connection Not API Standard Feature: . c. Nonstandard bit connection. Advantage: Allows nonstandard box connection for a given bit size, to minimize length between bit box and turbine or motor pin Benefit: . Provides stabilization, reduces bore hole spiraling, and provides additional gauge protection. I Feature IF Connection Feature: . i. IF connection replaces standard connection. Advantage: Allows bit conformity to connection type of directional tools Benefit: . Provides more flexibility in configuring a drilling assembly. 34.

(39) Fixed Cutter Bits Nomenclature. Product Line. Prefix Description. Face Features. Description. A. ARCS & ARCS advanced. K. Impregnated cutter backing. C. Carbonate. L. Low exposure. D. Natural diamond bit. M. Replaceable Lo-Vibe. Di. IDEAS certified directional design. V. Lo-Vibe. G. Reamers with API connections (box down, pin up). H. Kinetic hybrid bit. Hydraulic Features. Description. HOX. Heavy oil series. H. Higher number of nozzles than standard. K. Kinetic impregnated bit. N. Lower number of nozzles than standard. L. LIVE. Q. Fixed ports. M. Matrix body. U. 50 series nozzles. PR. Pilot reamer. W. 40 series nozzles. QD. Quad-D dual diameter. Y. 30 series nozzles. R. ONYX 360 rolling cutter. S. Steel body. Gauge Features. Description. S. SHARC. A. Active gauge. ST. Side track. B. Back reaming cutters. SHO. Staged hole opener. D. Dog sleeve. T. Turbine. E. Extended gauge pad length. V. VertiDrill. PX. TSP on gauge. Z. Stinger—conical diamond element. PXX. Full diamond on turbine sleeve. S. Short gauge pad length. T. Turbine sleeve. Nomenclature identifies blade count/cutter size. Example: M616 = 6 Blades /16 mm cutters. Connection Features Description C. Non API standard connection. I. IF connection. Nomenclature example. M S i R 6 16 M H PX PX – TSP on gauge (Gauge feature) H – Higher number of nozzles than standard (Hydraulic feature) M – Replaceable Lo-Vibe (Face feature) Cutter size Blade count R – ONYX 360 rolling cutter (Product line) i – IDEAS certified (Product line) S – SHARC (Product line) M – Matrix (Product line). 35.

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(41) Roller Cone Products. 37.

(42) Roller Cone Bits Product Line 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. Kaldera ■■. Roller cone products for geothermal and high-temperature applications. 38.

(43) Roller Cone Bits. Gemini—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. 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.. Size Type Availability, in. 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 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.. Bearings. 83⁄8. GF15, GF20, GF40, GFi50. 81/2. GF05, GF06, GF08, GF10, GF15, GF20,GF25, GF30, F30, GF40, GF45, GF50, GF65, GF80, GFA21, GFi08, GFi10, GFi12, GFi20, GFi23, GFi28, GFi30, GFi45, GFi50. 85⁄8. GF15, GF45. 83/4. GF10, GF15, GF27, GF40. 91/2. GF20, GF21, GF30, GF45, GFVH. 115⁄8. GF15, GF20. 12. GF10, GF20, GF28. 121/4. 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+. 143/4. G10, G15, G25, G40. 16. G18, GGH+, MGGH+. 171/2. G02, G10, G15, G28, G30, Gi01, Gi03, Gi12, GGH+. 22. Gi06. 24. G04. 26. G04, G28. Gemini bits can be equipped with roller bearings (bit size ≥ 12¼ in) or friction bearings (bit size ≤ 12¼ in).. Cutting Structure. Different 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.. Gemini nomenclature. GF i 35 Cutting structure i – IDEAS certified G/GF – Gemini designation. www.slb.com/Gemini. 171/2-in Gi03. 39.

(44) Roller Cone Bits. Shamal Hard Carbonate-Optimized TCI Drill Bit Shamal drill bits are designed for hard carbonate drilling, with specifically designed tungsten carbide inserts. The Shamal* product line incorporates a range of TCI bits developed for maximizing performance in hard carbonate formations.. Size Type Availability, in 81/2. These bits use a range of proprietary, coarse carbide grades, which are designed to combat heat checking and subsequent chipping and breakage of inserts, the primary dull characteristics when drilling hard carbonates. Incorporating unique cone layouts and insert geometries, the Shamal product line is providing superior ROP and durability in challenging applications throughout the world.. 83/4. GFS15. 115⁄8. GFS30. 12. GFS28. 121/4. GFSi01, GFS04, GS04, GFS05, GS05, GFS06, GFSi06, GFS10, GS10, GFS11, GFS15, GS15, GFS20, GFS26, GFS30, GFSi28. 143/4. GS10. 151/2. GS10. 16. GS03, GS10, GS12, GS18, GS30, GSi01, GSi03, GSi06, GSi12, GSi15, GSi18, GSi20. 171/2. GS03, GS05, GS10, GS12, GS15, GS18, GS28, GSi01, GSi12, GSi18. 22. GS04, GS12, GSi06, GSi12. 231/2. GS04. 24. GS18. 26 28 36. GS04, GS18 GS04, GS18, GSi18 GSi15. Shamal tungsten carbide. Shamal nomenclature. G S i 05 Cutting structure i – IDEAS certified S – Shamal feature G – Bearing prefix. www.slb.com/Shamal. 12¼-in GFS05BVCPS. 40. GFS05, GFS06, GFS15, GFS20, GFS30, GFSi10, GFSi23, GFSi28, MFS04, MFS10T, MFS20B.

(45) Roller Cone Bits. Xplorer Premium Slim Hole TCI Bit Xplorer drill bits provide consistently superior performance in applications ranging from very soft to ultrahard formations. Maximum steerability and strength. Size Type Availability, in. Xplorer* slimhole TCI drill bits have ultrashort leg forgings, which maximize steerability at extreme build angles, enabling the most demanding directional programs. The forging design also strengthens the chassis and meets the hydraulic demands of modern drilling.. Harder-wearing seals. To handle the high rotation speeds typically seen in the formations 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.. 33/4. XR20, XR40. 7. 3 ⁄8. XR30, XR50. 41⁄8. XR30, XR50. 41/2. XR30. 45⁄8. XR30, XR50. 43/4. XR15, XR20, XR30, XR40, XR50, XR70. 47⁄8. XRi15, XR20, XR30, XR50. 51/2. XR20, XR40. 5 ⁄8. XR30, XR40, XR50. 57⁄8. XR15, XR20, XR30, XR40, XR50, XRi40, XRi50, XRS15. 6. XR10, XR12, XR15, XR20, XR30, XR40, XR45, XR50, XR65, XR70, XRS30, XRi15, XRi20, XRi40, XRi45, XRi50. 61⁄8. XR10, XR15, XR20, XRSi20, XR25, XR30, XRi30, XRi35, XR38, XR40, XR50, XR60, XRi65, XR68, XR70, XR90, XR35, XRi20, XRi28, XRi40, XRi45, XRi50, XRKi65. 61/4 61/2. XR20, XR30, XR40, XR50, XR70, XRi30, XRi35, XRi45 XR10, XR15, XR20, XR30, XR40, XR45, XR50, XR60, XR68, XR70, XR90 XR10, XR20, XR25, XR32, XR40, XR50, XRi30. 5. 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 structures. 63/4. Individual 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.. Xplorer nomenclature. XR i 20 Cutting structure i – IDEAS certified XR – Xplorer designation. www.slb.com/Xplorer. 61/2-in XR20T. 41.

(46) Roller Cone Bits. Xplorer Expanded Soft-Formation Milled Tooth Drill Bit Milled tooth bits that are specifically designed to drill soft to firm formations. Enhanced ROP. Xplorer 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.. Type. Size Availability, in. XR+. 41/2, 43/4, 47⁄8, 5, 51/2, 55⁄8, 53/4, 57⁄8, 6, 61⁄8, 61/4, 61/2, 63/4, 77⁄8, 83⁄8, 81/2, 83/4, 91/2, 97⁄8, 105⁄8, 115⁄8, 121/4, 131/2, 133/4, 141/2, 143/4, 15, 151/2, 16, 17, 171/2, 181⁄8, 181/2, 191/4, 20, 213/4, 22, 23, 24, 26, 31, 32, 321/4, 323⁄8, 33, 36. 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 bearings. All Xplorer Expanded bits with 81/2-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 13½ in and greater incorporate premium sealed roller bearings.. Xplorer nomenclature. XR + Premium milled tooth cutting structure XR – Xplorer designation. www.slb.com/XR-expanded. 171/2-in XR+ ODVEC. 42.

(47) Roller Cone Bits Kaldera Bit. Roller Cone Products for Geothermal and High-Temperature Applications Geothermal and high temperature drill bits. Size Type Availability, in Milled Tooth. 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.. Proven durability in high-temperature applications. Tested against baseline bits, in geothermal superheated steam applications where temperatures can reach 530 degF, the new Kaldera roller cone bit was clearly the top performer: Average run length was 33% greater. XRK+. XRK40 1. 6 ⁄8. XRK40. 77⁄8. FHKi30. 81/2. 47YGA, FHK15, FHK30, FHK45, FHKi40, FHKi50, FHKi69. 9 ⁄8. FHK30, FK47, FK50, FK57. 105⁄8. GFK47. 121/4. 47YG, GFK15, GFK30, GFKi28, GFK10. 17. GSK20, GSKi18. 22. GSKi12. 7. Kaldera high-temperature roller cone drill bit represents a new line of bits with an innovative bearing system that comprises new proprietary composite elastomer seals with specialized fabric compounds and a proprietary high-temperature grease formula. These innovations increase seal life, lubricity, and load capacity at elevated temperatures for HT applications.. ■■. 81/2. 6. Drilling for unique energy calls for a unique bit. On-bottom drilling time was 3% to 37% greater. XRK+. TCI. At that temperature, a standard 300 degF-rated bit’s 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.. ■■. 57⁄8. Kaldera milled tooth nomenclature. XRK + Premium milled tooth cutting structure XRK – Xplorer-Kaldera designation. Kaldera TCI nomenclature. GFK 47 Premium TCI cutting structure GFK – Gemini-Kaldera designation. www.slb.com/Kaldera 43.

(48) 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 structure. Size Type Availability, in. FH* 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 bearings. The 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 frictionreducing effects of the silver, combine to create a longer lasting, highly reliable bearing package.. 77⁄8. FHi20, FHi21, FHi23, FHi24, FHi26, FHi28, FHi30, FHi35, FHi38, FHi40, FHi45, FHi50, FHi43, FHKi30, FH25, FHi08, FHi18, FHi37, FHi39. 81/2. FH23, FHi04, FHi20, FHi21, FHi28, FHi40, FHi69, FH30, FH35, FH40, FH45, FH50, FHi90, FHK08, FHK30, FHKi 40, FHKi50, FHKi69. 83/4. 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. 97⁄8. FH23, FH28, FH30, FH35, FH40, FH45, FH50, FHi12, FHK30. 121/4. FH24, FH50. Application-specific hydraulics. The 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.. FH nomenclature. FH i 28 Cutting Structure i – IDEAS Certified FH – FH Designation. www.slb.com/FH. 83/4-in FH28GVPS. 44.

(49) Roller Cone Bits. TCT Two Cone Drillbit Technology More aggressive roller cone designs 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.. Size Type Availability, in. Optimal cutting structure. 83/4. TCTi+, TCT20, TCT37. 97⁄8. TCTi+. 121/4. TCTi+, TCT11, TCT12, TCTi11. 61/2. TCTi+. 7 ⁄8. TCTi20. 81/2. TCTi+. 7. Extensive analysis ensures that the cutting structure layout optimally exploits the bit’s 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.. 16. TCT+, TCTi+. 171/2. TCT10, TCTi+. Five-nozzle hydraulic configuration. TCT 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 stability. Two-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 system. 121/4-in MT TCTi+. The 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.. TCT nomenclature. TCT i + Premium Milled Tooth Cutting Structure i – IDEAS Certified TCT – TCT Designation. www.slb.com/TCT. 121/4-in TCI TCTi. 45.

(50) Roller Cone Bits. Standard Milled Tooth, TCI and Open Bearing Bits 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. 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. Size Type Availability, in 33/4 63/4. OFH, OFM. 6. FDGH, FHV. 71/2. FDT. 7 ⁄8. FDS+, FI18, F26Y, F27Y, F27iY, F30Y, F37HY, FI39HY, F45H, F47HY, F47YA, F49YA, F57Y, F59HY, F67Y, F80Y, F85Y, F90Y. 83⁄8. MFDGH, SVH, F37Y, F57Y. 81/2. F10, F37HY, F37Y, F47HY, F57Y, F67Y, F80Y, F85Y, FDGH, FDS+, MFDGH. 83/4. FDS+, F12V, F26Y, F27iY, F30T, F37HUY, F37HY, F39HY, F40YA, 46HY, F47HY, F47YA, F50YA, F59Y, F67Y, F80Y, F85Y, F90Y. 87⁄8. F40YA, F50YA. 91/2. FDS+. 97⁄8. FDS+, F10B, F37Y, F47HY, F59Y, F67Y, F80Y, F85Y, F90Y. 105⁄8. F37, F47Y, F67Y, F85Y, F90Y. 11. F20, F20Y, F27Y, F37Y, F47Y, FDS. 115⁄8. F30, F47Y, FDGH, MSVH. 121/4. F25Y, F37Y, F40, F47YA, F57, F67, F80Y, F90Y, FDGH, FDS+, FDT. 143/4. F30. 17. MSDGH. 171/2. DSJ. 20. MSDGH. Cutting Structure. 22. MSDGH. F – Bearing Prefix. 23. DSJ, MSDGH. 26. DSJ, MSDGH. 28. MSDGH, DSJ. 32. MSDSSH. 34. MSDGH. 36. DSUJ. 7. 121/4-in FVH. Standard nomenclature/Milled tooth bits. FVH H – Heel Inserts V – Medium to Hard Formation Type F – Bearing Prefix. Standard nomenclature/TCI insert bits. F 12. www.slb.com/rockbits. 83/4-in F12. 46.

(51) Roller Cone Bits Optional Features. TD Feature Diamond-Enhanced Trucut Gauge Protection. td. Feature: . Diamond-enhanced, semiround-top, on-gauge inserts provide finish cut-to-gauge for Trucut* drillbit gauge system with 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 and quality, in-gauge boreholes. SD Feature Shaped Diamond-Enhanced Gauge Inserts. sd. Feature: . Shaped 100% 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. D Feature Diamond-Enhanced Gauge Row Inserts Inserts. d. Feature: . Diamond-enhanced gauge inserts. Advantage: Substantially reduced gauge-row wear and breakage rates; greater wear-resistance in highly abrasive applications Benefit: . 47. High-quality, full-gauge wellbore over longer intervals compared with tungsten carbide gauge inserts.

(52) Roller Cone Bits Optional Features. B Feature Binary Gauge Protection Feature: . b. 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 Protection Feature: . bd. 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 Protection Feature: . T. TCI protection for Trucut* drillbit gauge system. Advantage: Improved gauge durability and integrity with a twin gauge-insert system composed of aggressive, neargauge inserts to drill the near-gauge and borehole corner with reduced scraping action, and semiroundtop, on-gauge inserts provide finish cut to gauge; significantly reduces stress on gauge inserts Benefit: . Extended bit-gauge life for longer intervals and highquality, in-gauge boreholes. OD Feature Diamond-Enhanced Heel Row Inserts Feature: . od. Up to 50% diamond-enhanced heel row inserts. Advantage: Improved resistance to abrasive wear and impact damage; protection for lower leg and bearing seal areas Benefit: . Extended bit-gauge life for longer intervals and highquality, in-gauge boreholes. 48.

(53) Roller Cone Bits Optional Features. OD1 Feature All Heel Row Inserts Diamond Enhanced. od1. Feature: . 51%–100% diamond-enhanced heel row inserts.. Advantage: The heel cutting structure is designed for the most abrasive environments, resulting in a longer gaugecutting-structure life, and protection 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 Structure. dd. Feature: . 100% diamond-enhanced cutting structure.. Advantage: Premium cutting structure for drilling very abrasive formations efficiently, with longer runs and lower weight on bit (WOB). Benefit: . High ROP and extended bit life.. G Feature Super D-Gun Cone Protection. g. Feature: . Super D-Gun* tungsten carbide cone protection.. Advantage: A hard, tungsten-carbide-based coating applied to cone shells increases resistantance to abrasion and erosion; ideal for highly abrasive formations that generate large volumes of cuttings; provides additional protection in abrasive and inefficient hole cleaning conditions: high angle, directional, and horizontal applications Benefit: . 49. Increased bit life, longer bit runs, and improved insert retention.

(54) Roller Cone Bits Optional Features Y Feature Conical Shaped Inserts Feature: . y. Conical shaped inserts. Advantage: Geometry optimized to reduce insert breakage Benefit: . Enables high ROP in formations sensitive to weight on bit (WOB). V Feature V-Flo Nozzle Configuration Feature: . v. V-Flo* vectored-flow nozzle configuration. Advantage: Jets are directed at leading side of following cone for maximum cleaning; enhanced bottomhole cleaning is achieved through efficient cuttings lift and strong, upward, helical flow Benefit: . Clean cutting structure in soft and sticky formations. VE Feature Extended Vectored Nozzle Sleeve (Available for 121⁄4-in and larger bits) Feature: . ve. Extended vectored nozzle sleeve. Advantage: Nozzle angles are precisely oriented to direct fluid flow to leading edge of cones, increasing cleaning efficiency Benefit: . Clean cutting structure, and maximum ROP through higher impingement pressure. 50.

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