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Headquarters16740 Hardy Street
Houston, Texas 77032(800) 877-6484
Phone: (281) 443-3370 Fax: (281) 233-5190www.smithbits.com
2008 Smith International. All Rights Reserved.Printed in the U.S.A. 04/08 SS01-3046
At Smith Technologies, our success is due to an unrelenting focus on three critical elements of our
business: People…Technology…Results. Our people are dedicated to providing the highest level of service
and technical support. Our technology leads the industry in drill bit design, materials science and
quantitative drilling application tools. And our results consistently confirm Smith Technologies' superior
performance and value.
Our ultimate goal is to provide solutions that drive down the cost of drilling your well. Whether the
application calls for a Smith Bits roller cone, PDC, diamond impreg, natural diamond, or percussion drill
bit; a Smith Neyrfor turbodrill; the expertise of our Advanced Services Engineers; or the sophisticated
simulation analysis of i-DRILL, Smith Technologies delivers proven solutions that will get the job done in
the most cost effective manner possible.
As the oilfield has grown and changed, so has Smith Technologies. From the opening of Herman Smith's
blacksmith shop in Whittier, California in 1902, to the global presence of our operations today, the
evolution of Smith Technologies has paralleled the growth of the energy industry world wide.
Smith Technologies offers a unique combination of engineering innovation; world-class products with
unsurpassed performance; and personal, highly responsive service. We are passionately committed to
providing our customers a superior solution to their most challenging drilling applications.
Source: EnergyPoint Research, Inc. Source: Hart’s E & P Magazine
Smith was rated #1 in customer satisfaction among all integrated service providers in the recent EnergyPoint Research, Inc. survey of operators.
For the ninth consecutive year, Smith Bits added to its longstanding position of industry leadership by once again being recognized as the holder of the most World Records for Drill Bit performance.
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SMIT
H B
ITS
§
§ Advanced Services Engineering - ASE ®
§ Drill Bit Optimization System - DBOS®
§ YieldPoint™
§ Drilling Record System - DRS
® i-DRILL Drilling Simulation Analysis
§ FH ®
§ Gemini®
§ Shamal Typhoon®
§ Shamal TNG®
§ XPlorer®
§ XPlorer Expanded™
§ TCT - Two-Cone Technology Roller Cone Bits
§ Standard Products™
§ Flex-Flo Hydraulics™
§ Typhoon Hydraulics
§ Insert Technology
§ Optional Features
§ Roller Cone Nomenclature
§™
§ SHARC PDC Bits®
§ VertiDrill PDC Bits™
§ Shaheen PDC Bits™
§ Kinetic Diamond Impreg Bits
§ Standard PDC Bits
§ Natural Diamond Bits
§ PDC Cutter Technology
§ Insert Technology
§ Computational Fluid Dynamics - CFD
§ Optional Features
§ Fixed Cutter Nomenclature
™ ARCS PDC Bits
§ Total Flow Area Chart
§ Drill Collar Specifications
§ Measurement Units & Drilling Formulas
§ Buoyancy Factor
§ Fixed Cutter Bit Nozzle Installation
§ 6-5/8” API Pin Restictor Nozzle
§ Fixed Cutter Bit Make-Up Torque
§ Fixed Cutter Bit Field Operating
Procedures
§ Maximum Cone Dimensions
§ Roller Cone Bit Make-Up Torque/Nozzle
Types
§ Roller Cone Bit Comparison Chart
®§ IMPAX Percussion Hammers® § IMPAX Percussion Bits
™ § DIGR Percussion Bits
IDEAS Technology®
Applied Technology
Fixed Cutter Bits
Roller Cone Bits
Turbodrills
BoreHole Enlargement
Percussion Hammers & Bits
Reference Tools
1 - 4
Table of Contents
5 - 11
12 - 31
32 - 51
52 - 55
56 - 63
64 - 69
70 - 84
IDEAS Technology
The Smith Bits division of Smith Technologies developed the IDEAS (Integrated Dynamic Engineering Analysis
System) bit design platform to serve a drilling industry that continues to push drill bit manufacturers for
application-specific bits, increased performance and greater reliability. The IDEAS design platform is a
revolutionary leap forward in truly understanding the rock/cutter interface in a dynamic drilling environment
where every individual element of the bottomhole assembly is
considered. Every new Smith Bits roller cone and PDC drill bit is
developed and certified through the IDEAS bit design process. The
IDEAS drill bit certification process not only results in designing and
producing better bits more quickly, but also significantly reduces the
level of risk for oil and gas companies.
The original objective of IDEAS was to produce improved bit designs
while significantly reducing product development cycle time. IDEAS
technology has met the original objective and, in the process, has
delivered a whole lot more. With the development of the IDEAS
certification process, Smith Bits design engineers now have the unique ability to rigorously evaluate and test
changes to a bit design in a matter of hours or days rather than weeks or months. The IDEAS analysis considers all
of the downhole components when evaluating the best bit design for the highest performance, including drillpipe,
hevi-wate drillpipe, MWD/ LWD tools, reamers, stabilizers and whether an operator is utilizing a push-the-bit or
point-the-bit rotary steerable system. When Smith Bits completes the bit design and analysis, the customer
receives a specific recommendation of the optimal bit as the best solution for the objective.
After a bit has been designed in IDEAS, the same rigorous modeling technology can be used to provide a detailed
applications analysis of how the bit will perform for a specific drilling program. Each customer is given an in-depth
analysis of the bit or bits evaluated, a description of the drill string and its components, proposed operating
parameters and the formations to be drilled, and precise performance projections. Among the data provided to
the customer, in addition to the bit analysis, are graphs illustrating the specific BHA configuration modeled for the
well, bit bottom hole pattern, bit center trajectory, weight on bit, lateral forces and lateral accelerations.
There are five basic elements to the bit design and performance advantages provided by
IDEAS.
• Comprehensive drilling system analysis: The IDEAS certification process includes
examining the designed bit performance in relation to the entire drill string and
individual BHA components. It also takes into account the specific operating
parameters and interaction of the individual elements of the entire drilling assembly.
• Holistic design process: Smith Technologies design engineers account for every
critical variable to assure that IDEAS-designed bits are optimized for performance. With the insight to bit
performance provided by IDEAS, virtually every cone or cutter layout and configuration is designed to
result in a stable bit that rotates around its center, the key to an efficient, optimized drilling operation.
IDEAS’ Five Basic Elements
®
IDEAS Technology Ensures a Better Solution.The First Time, Every Time.
1
IDEAS Technology
• Application-Specific Enhancements: As a result of the drilling system analysis and holistic design
process, IDEAS certified bits include performance enhancements specific to the application for which it is
designed. This results in bits that consistently outperform previous designs when measured against the
same parameters and objectives, including, for example, improved rate of penetration (ROP), durability,
or specific bit behavior when utilized with a rotary steerable system. IDEAS certified bits are consistently
dynamically stable within the operating envelope for which they are designed, resulting in longer bit runs
and less stress on the BHA, which ultimately results in improved bit durability.
• Rapid Solutions with Reliable Results: By using sophisticated modeling tools and accounting for a
multitude of dynamic variables in a virtual environment, IDEAS certified bits move through the design
stage much more quickly and with a greater level of reliability and performance than ever before. The
IDEAS modeling capability removes the trial-and-error approach previously associated with designing
drill bits by using laboratory tests to quantify variables such as cutter forces and rock removal rates. The
IDEAS process can prove the efficacy of the drill bit design before moving to field trials, ensuring that drill
bits that move to the field trial stage are true candidates for the application for which they were designed.
• Optimized Integration of Advanced Materials: The IDEAS process also allows Smith Bits to more
effectively employ advanced cutter materials. Stronger and more durable materials work in conjunction
with IDEAS design and simulation capabilities to deliver a bit that is more than just correcting a design for
weak and high-wear areas. The result is a bit with an optimal design for high performance and abrasion
and impact resistant cutters.
®
IDEAS Technology Ensures a Better Solution.The First Time, Every Time.
Because the IDEAS process avoids the costly and time consuming trial-and-error requirements of the traditional drill bit design process, Smith Bits can deliver a better solution, faster.
2
Conducting virtual case studies
The IDEAS process certifies the performance capabilities of each bit design through a dynamic simulation and
modeling methodology that takes into account the lithology at the rock/ cutter interface, the drill string, the drive
system, the BHA and the total system's influence on the bit's behavior.
The IDEAS process begins with bit performance data, geological information, BHA details and dull bit analysis.
With this data, actual laboratory rock/cutter tests are devised and carried out. The laboratory data from IDEAS
quantifies the actual cutter forces and rock removal rates, compared with other bit design tools that only estimate
rock/cutter behaviors. This information is then
used for the design analysis in lithologies that
compare to the particular field application for
which the bit is being designed.
The IDEAS design platform incorporates the
quantitative understanding of rock chip
generation and removal, for each individual
cutter, into a dynamic model of the total drill
string, from the BHA to the surface drive
mechanism. When the actual rock/cutter
data is obtained, it is integrated into a full bit
d e s i gn mode l t o de t e rm ine t he
characteristics of the bit in actual drilling
conditions.
The virtual case study quantifies the effects
of design changes in roller cone and fixed
cutter bit profiles, gauge lengths, cone
offsets for roller cone bits to determine
bottom-hole patterns and bottom-hole forces. These parameters are examined in a fully dynamic simulation
model where bit influences are identical to those encountered in the actual drilling environment.
The model analyzes rock/cutter interface, BHA configuration, drill string behavior, directional response, dynamic
analysis of projected bit behavior, and how changes in operating parameters affect bit performance. This data set
allows the design engineer to fine-tune the bit for a particular field application based upon the desired objectives
such as ROP, footage to be drilled, enhanced durability or specific directional behavior for use with rotary
steerable systems.
The result is a drill bit that is dynamically stable within the operating and application parameters for which it is
designed, contributing to longer life, faster ROP and increased reliability for downhole electronics. Optimized
parameters can be maintained for faster, longer bit runs with less stress on the BHA and rig equipment.
IDEAS Technology ®
®IDEAS Technology Ensures a Better Solution.The First Time, Every Time.
3
The IDEAS Directional Certification process can account for the specific attributes of every different type of rotary
steerable system and accurately predict bit performance in any directional application, allowing Smith Bits
engineers to design fixed cutter bits that are dynamically stable across a range of demanding directional
applications .
IDEAS bit designs are developed using highly sophisticated simulation software, which accurately models the
total drilling system, from where each individual cutter contacts the formation, through each component in the
BHA, all the way up to the surface drive mechanism. Additionally, with IDEAS,
all the different types of rotary steerable systems can be accurately modeled
individually.
By using IDEAS technology, it is possible to precisely model and predict how
several different IDEAS bit designs will perform in specific formation types,
with a specific rotary steerable system, specific operating parameters and a
specific bottom-hole assembly configuration. It's like having the opportunity
to drill the same interval multiple times with different bits and then being able
to pick the best one for the application.
Extensive IDEAS Directional Certification analyses ultimately provided an extremely important revelation: a
single bit design can, in fact, provide exceptional drilling performance when used with a range of different types of
directional drilling systems, provided the bit has been designed to remain dynamically stable. The use of IDEAS to
analyze conventional directional bit designs has revealed that, in many instances, the range of special directional
features incorporated into older conventional bits serve as little more than a crutch that allows a basically
unstable bit design to drill acceptably in a specific directional application. However, when this bit is subsequently
used with a slightly different BHA or in a different application, its unstable character is revealed thus requiring a
new or significantly modified bit to again compensate for the inherent instability of the design under the new
conditions.
With IDEAS, a bit designer no longer needs to focus on stabilizing an unstable bit design, and instead the designer
can concentrate more on optimizing the blade count, cutter selection, cutter layout and hydraulic configuration to
make the bit drill faster and last longer. In general, directionally certified IDEAS bits can have reduced blade
counts, larger diameter PDC cutters and lower back rake angles relative to conventional directional bits. The large
diameter cutters establish full bottom-hole coverage, generate higher loads per cutter, and provide greater depth
of cut to maximize ROP. All of these characteristics are matched to the drillability characteristics of the different
formations and specific lithologies.
IDEAS bits are directionally certified to remain stable and provide superior performance with
different types of steering systems in a wide range of applications, reducing risk of suboptimal
performance should it become necessary to change the system configuration, operating
parameters or something else due to unforeseen developments. Also, experience has shown
that drilling with a stable bit not only reduces drilling costs, it also provides a smoother, high
quality wellbore.
IDEAS Directional Certification fixed cutter bits keep directional wells and drilling budgets on target.
IDEAS Directional Certification of Fixed Cutter BitsImproves Performance, Reduces Risk and Keeps Directional Wells on Target.
IDEAS Technology ®
4
i-DRILL 4D modeling predicts a drilling system's performance and behavior using detailed geometric input
parameters anticipated operating parameter ranges, extreme computing power, finite element analysis and lab-
derived rock mechanics data. i-DRILL provides a unique approach that allows a complete drilling system analysis
instead of the common practice used in the past of assuming bit-effect factors. i-DRILL provides clients with the
opportunity to eliminate the costly exercise of learning through trial-and-error.
By utilizing a time-based model with six degrees of freedom, the 4D modeling accurately predicts the vibrations
and accelerations often seen to have detrimental effects on directional control, tool reliability, drill string integrity
and drilling performance.
The ability to pinpoint the sources and
effects of torsional, axial, and lateral
oscillations enables drilling engineers and
directional drillers to quantify design
changes to the drillstring configuration
and optimize parameters. Excessive
bending stresses and buckling are
commonly seen as major contributors to
downtime. i-DRILL provides an in-depth
understanding of a drilling system's
integrity, achieved by evaluating bending
moments in two directions. Directional
tendencies are predicted by examining the
forces generated by bit-rock interaction
with the dynamic effect of the entire
drillstring. i-DRILL gives the client the
chance to focus on any discrete
component of the drillstring to evaluate
and understand that specific component's
contribution to overall performance.
The virtual world meets real world through
the coupling of rock mechanics lab data
with highly advanced proprietary
software. Heterogeneous formations and transitional drilling can be modeled and combined with benchmark
outputs such as torque & drag and critical speeds.
i-DRILL’s extensive tool portfolio includes the differentiation between push- and point-the-bit rotary steerable
systems, concentric and eccentric reamers, positive displacement motors, hole openers, and roller reamers, just
to list a few.
i-DRILL delivers to the energy industry the tremendous potential to change the way wells are drilled in the future,
and it is yet another example of SMITH being at the forefront of drilling technology development.
Eclipsing All Other Drillstring Analysis Programs
Applied Technology
5
Smith's technology and engineering expertise in customers' offices
Providing expert drill bit selection
Measurable results are what matter most to the operator, and Smith Technologies Advanced Services Engineering
(ASE Organization) has built an impressive track record of lowering operators’ drilling costs through improved
drilling performance by recommending the ideal bit for the application.
Smith Bits' Advanced Services Engineering (ASE) is an independent applications organization within Smith that
provides expert drill bit selection and well planning engineering to its customers. ASE engineers become an
integral part of customers' drilling teams, recommending the correct drill bits to optimize performance and
reduce the operators’ drilling costs.
Objectivity is the fundamental principle of the ASE program. Bit recommendations by Smith Technologies ASE
engineers are always based upon the best product for the specific application regardless of the drill bit
manufacturer. No one company makes the ideal bit for every application and ASE engineers will recommend a
competitor's bit where it is appropriate.
The Smith Technologies ASE program provides a highly experienced bit application specialist to a customer's
drilling team to generate objective bit recommendations and advise both the operator and Smith on day-to-day
requirements for maintaining superior bit performance.
ASE engineers consider the entire drilling environment, including formation, the components of the BHA, drilling
fluids, rig capabilities, rig crew and any special drilling objectives in their process of finding an optimum bit and
then maintaining its efficiency throughout the bit's life.
The ASE engineer is also armed with several Smith Technologies proprietary tools, such as Smith Bits' Drilling
Records System™ (DRS), which includes detailed bit runs from oil, gas and geothermal wells from around the ®world; the Drill Bit Optimization System (DBOS), which helps determine the appropriate combination of cutting
structure, gauge protection, hydraulic configuration and other bit optimizing features; and Yield Point software
for jet nozzle optimization.
To establish measurable goals, the ASE engineer prepares a comprehensive well plan that evaluates performance
during drilling. Upon completion of the well, a post-well analysis measures the success of the well plan and
provides a permanent formal reference for future development wells.
Applied Technology
6
Advanced Services Engineering
Advanced Services Engineering
Applied Technology
Planning the well
Post Well Analysis
The well planning process begins with support from DRS, DBOS and Yield Point software as well as the ASE
engineer's own expertise and experience in the field of drill bit applications around the world. Utilizing the
knowledge gained from an analysis of offset wells from the DRS and a spectrum of other relevant information, the
DBOS program is used to begin preparing the well plan. The DBOS analysis begins with a thorough reconstruction
of expected lithologies gleaned from well logs from the closest offset wells and includes a formation analysis,
unconfirmed rock strength analysis and both roller cone and fixed cutter bit selections.
Operational needs and the well plan are added, including casing points and hole sizes, well directional plot,
expected formation tops, and mud weights and types. The result is an optimized minimum cost per foot program,
often with multiple options and alternatives.
Smith's Yield Point software creates a graphical user interface to aid drilling engineers in specifying mud types
and properties to satisfy rheological models of drill strings and well annuli. Yield Point can answer questions about
hole cleaning using data from the formations to be encountered. Utilizing a cuttings transport model, the software
can be used to assess potential hole-cleaning problem areas during the well planning stage rather than
encountering problems during actual drilling operations.
The appropriate rig and office personnel are briefed on the drilling program and monitor the well prognosis during
implementation of the well plan. Any problems that arise are identified and investigated, and decisions are made
to correct the issues, subject to the objective of maintaining peak drilling efficiency in a safe and timely manner.
A thorough performance assessment is conducted upon completion of the well, which evaluates every facet of the
drilling operations. The drilling team, including the ASE engineer, makes recommendations for improvements
that will be incorporated into future well plans.
Smith's ASE program and its objectivity provide value to Smith's customers by recommending the best bit for the
specific application and, in turn, provide the most efficient and economical drilling solution to the customer.
7
DBOS™ delivers a better bit program for achieving lower cost per foot drilled.
The DBOS evaluation process
The Smith Bits’ DBOS (Drill Bit Optimization System) service can deliver the minimum cost per foot with a higher
degree of certainty and reduced risk by identifying the best bit, from the vast Smith Bits portfolio, to match the
physical characteristics of the interval to be drilled.
DBOS is a software-based process which identifies the Smith fixed
cutter or roller cone bit that has the appropriate combination of
cutting structure, gauge protection, hydraulic configuration and
other features needed to achieve the lowest cost per foot drilled for
the operator. The DBOS service incorporates a thorough analysis of
offset well data including well logs, formation tops, mud logs, core
analysis, rock mechanics, drilling parameters, bit records and dull
bit conditions.
The software tools use a geologic mapping program, well log
correlation and analysis software, and proprietary Smith Bits
algorithms for rock compressive strengths, bit performance
analysis and bit selection. The DBOS service is highly flexible, allowing Smith Bits engineers to analyze various
levels of information and deliver a bit strategy based on input from, for example, a single offset well, a multi-well
cross section, or a full field mapping and regional trend analyses.
The DBOS service has been offered for over 15 years, creating a supporting database containing records from
more than 8,750 projects in 56 countries, encompassing more than 12,500 wells. Operators around the world
have attributed significant savings in drilling time and cost to use of the DBOS service.
The process begins with an evaluation of the expected formation types that may be encountered in an interval and
their associated section lengths. Data are obtained from offset well logs. DBOS then determines unconfined rock
compressive strength, effective porosity, abrasion characteristics and impact potential. The rock properties will
help identify one or more potentially optimal bit types and DBOS identifies various applicable bit characteristics
based on its analysis. Hydraulic configuration, cone layout, insert type, gauge protection, cutter type and
diameter, blade profile and cutter density are examples of bit characteristics that are evaluated. DBOS also
predicts cost per foot that each bit will achieve and makes recommendations for the bit type with the minimum
cost per foot.
Various levels of the DBOS service are offered and, for each level, DBOS data are presented graphically to
customers in a log plot form called a Bit Performance Analysis (BPA). The parameters include bit record
information, directional surveys, real-time ROP and mud log data, rock type and strength data, and hydraulic and
mechanical energy factors, among other information. The BPA evaluates key bit performance variables over the
given drillability intervals, identifying which bit type would be the most successful for drilling through particular
single intervals or over multiple intervals.
Following the well, post-run analyses evaluate bit performance from available data such as real-time ROP, weight-
on-bit, RPM, torque, dull bit conditions and other parameters. The results of this analysis provide design and
application engineering feedback for continuous improvement.
Drill Bit Optimization System
Applied Technology TM
8
Optimized hole cleaning with Yield Point solutions
Yield Point RT for real-time assessment
Data Input to Yield Point
Smith Technologies developed the Yield Point drilling hydraulics and hole cleaning simulation program to aid
drilling engineers in specifying mud type and mud properties to satisfy rheological models of drill strings and well
annuli. Yield Point can identify potential hole cleaning problems in the planning stage rather than during drilling
operations when problems can affect the cost of the well.
This comprehensive drilling hydraulics and hole cleaning
optimization program uses sophisticated algorithms to
deliver solutions for conventional jet nozzle optimization
and selection. After initialization data is input, Yield Point
creates simulations of mud properties, flow rates, rates of
penetration and total flow area. The virtual model then
demonstrates the respective effects on observed bit
hydraulic factors and on hole cleaning.
Smith's most advanced version of the Yield Point platform is
Yield Point RT. It uses WITSML (well site information
transfer standard markup language) capabilities that
enable a customer's well data to be linked directly to Yield Point RT. The data can be analyzed virtually in real
time, resulting in recommendations for the operator that can be implemented immediately. Hydraulics can be
optimized to maximize efficiency as the well is being drilled.
By linking a customer's well data directly to Yield Point RT, the virtual model can include data from numerous
contributors. Using the WITSML defined standard and any common Internet connection, virtually all information
created at or around a well site can be transferred to a common WITSML data store for further retrieval and use
by authorized parties, beginning with the well operator and including various vendors and service providers that
contribute their data.
Wellsite providers, as well as off-location users, can input and retrieve data from Yield Point via an Internet
connection. These include drilling contractors, mud loggers, rig instrumentation and wireline companies, drilling
fluid service companies, casing running services and directional drillers. Operator personnel can include, drilling
and exploration engineers and managers, reservoir engineers and management personnel. Other service
providers include seismic survey companies, process optimization consultants and 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. Their information can support
programmatic analysis, visualization and potential corrective actions, and influence decision making in drilling
and production operations.
Operating company personnel can compile information from any mix of vendor sources, can view and monitor
current wells via web-based applications and can extract reports at any time.
The result is a real-time solution that yields substantial cost savings to the customer.
®
® Yield Point Hydraulic Analysis
Applied Technology
9
DRS Offers the Industry's Best Library Of Bit Run Information
The Smith Bits Drilling Record System (DRS) is a collection of nearly three million bit runs from virtually every oil
and gas field in the world. This database was initiated in May 1985 and, since that time, records have been
continuously added for oil, gas and geothermal wells. The Smith Drilling Record System (DRS) contains a wealth
of information that enables our design engineers to evaluate individual bit runs anywhere in the world. Armed
with this detailed set of data and the extraordinary capabilities of the IDEAS design system, engineers can
simulate bit performance, and make changes to their bit designs to optimize performance in a specific application.
In addition to its use as a database for bit design, the DRS system also allows Smith's DBOS (Drill Bit Optimization
System) to provide an accurate well plan for a customer to ensure that the right bit is run in a given formation.
With this comprehensive plan in place prior to beginning to actually drill the well, our customers are able to reduce
risk, lower drilling costs, and shorten the total time required to drill their well.
The inclusion of bit record data from your wells in Smith's DRS contributes to better drill bit selection and
application for your drilling program. The Smith Bits DRS can be accessed through your Smith Bits Application
Engineer or Sales Representative.
Drilling Record System™
Applied Technology
10
Fixed Cutter Bits
ARCS - Alternating Radius Curvature Stabilization
The ARCS concept improves fixed cutter bit performance by re-defining and optimizing the relationships among
rate of penetration (ROP), bit stability and cutter durability. This product line is specifically designed to extend
fixed cutter limits into geologically demanding applications. All new ARCS designs are IDEAS certified.
M/S - Matrix or Steel
ARCS Nomenclature
A - ARCS Technology
8-3/4” MAi513MSBPX
M A
ARCS combines multiple sized PDC cutting elements to define a
unique cutting structure governed by geometric relationships that
optimize bit performance. Through this use of multiple cutter
sizes, ARCS improves stability, ROP and durabilitybit cutter .
Extending the Limits
™ARCS
Type Size Availability
6-1/8”MA613MA616MA619MA816MA819MA913MA916MAi513MAi619MASi513 *
1 3 Cutter Size (Largest)
5
Blade Count
5-1/2” - 6-3/4”, 8-1/2” - 12-1/4”
8-1/2”, 12-1/4”, 16-3/8”
8-1/2”
8-1/2”, 9-1/4”, 12-1/4”
5-3/4” - 6-1/8”, 8-3/8”, 8-1/2”
6”, 8-1/2” - 12-1/4”, 15-1/2”
6”, 7-7/8”, 8-3/4”
8-1/2”
7-7/8”, 8-3/4”
i
i - IDEAS Certified
13* ARCS Sharc Bit
M/S - Matrix or Steel
SHARC Nomenclature
S - SHARC
14-3/4” MDSi619HBPX
M S i
SHARC high performance bits for tough formations
Drilling abrasive formations
When drilling hard, highly abrasive formations, Smith Bits SHARC Fixed Cutter bits will survive drilling the target interval
without sacrificing rate of penetration. SHARC fixed cutter bits drill faster and stay downhole longer in a time, a critical
advantage when rig rates continue to increase and drilling programs become more demanding.
Initially proven in the toughest East Texas formations such as the Travis Peak, Cotton Valley and Hosston, and in the
Northern Louisiana basins in the ArkLaTex region, Smith's SHARC PDC bits are now achieving superior performance in
challenging applications all over the world.
The key to achieving both bit durability and maximum ROP is maintaining drill bit stability across a broad range of
downhole conditions. SHARC bits are designed using Smith's patented IDEAS process specifically to eliminate vibration,
resulting in maximized stability for superior wear resistance. Cutter damage is minimized, meaning drilled footage is
maximized and, since sharp cutting edges are retained longer, rate of penetration (ROP) is maintained at a higher level.
SHARC bits have the durability to eliminate unnecessary trips, thus saving time and costs for the operator. SHARC bits
are available with IDEAS certification or IDEAS directional certification.
In early drilling tests, a SHARC design fixed cutter bit drilled 36% more footage than a conventionally designed bit under
similar conditions. Both bits were run until their cutters reached 1-1 dull grade wear flat. At the end of the runs, the
SHARC design bit drilled 1,050 ft compared to 732 ft for the conventionally designed bit. These early results have been
substantiated by numerous real world performance comparisons documenting the ability of dynamically stable SHARC
bits to out-drill the competition.
Smith Bits has developed cutters that complement the SHARC design's capability for drilling abrasive formations. The
latest technologies in materials, diamond interface design and manufacturing processes are utilized to deliver
significantly more wear resistance than cutters run in conventional applications.
Like a shark's multiple rows of teeth, SHARC's cutting structure layout features two rows of cutters set on certain blades.
Each individual 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 bit's double rows of cutters 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 fast surface intervals or when
hydraulic energy is compromised, for example, on motor runs.
SHARC™
Type Size Availability
7-7/8”, 8-3/4”
MDSi613MDSi619MSi416MSi513MSi516MSi519MSi611MSi613MSi616
MSi711MSi716MSi816
MSi1013
1 9 Cutter Size
6
Blade Count
7-7/8”
6-3/4”, 7-7/8”, 8-3/4”
8-3/4”, 12-1/4”
6”
6”, 6-1/8”, 6-1/2”, 7-7/8”, 8-1/2”
6”, 7-7/8”, 8-1/2”, 8-3/4”, 9-7/8” 12-1/4”, 14-3/4”
5-7/8”, 6”
7-7/8”
i - IDEAS Certified
Smith High Abrasion Resistance Configuration
7-7/8”, 8-3/8”, 8-1/2”, 8-3/4”9-7/8”, 12-1/4”, 16”
12”
5-7/8”, 8-3/4”
14-3/4”
D
D - IDEAS Directional Certified
14
6-1/4” MV613LYPX
VertiDrill™
Type Size Availability
6-1/8”MV513MV516MV613MV616MV716
MVi616
6-1/2”
6-1/2”
7-7/8”, 8-3/4”
7-7/8”, 8-1/2”, 8-3/4”, 9-7/8”11”, 12-1/4”
7-7/8”
VertiDrill Nomenclature
M/S - Matrix or Steel
V - VertiDrill
M V i 1 3 Cutter Size
6
Blade Counti - IDEAS Certified
VertiDrill bits maintain a vertical profile in faulted and fractured formations without using costly active steering systems.
A vertical wellbore without expensive directional tools
How it works
Smith Bits' VertiDrill line of fixed cutter bits is designed to maintain a vertical trajectory, or correct wellbore
inclination to vertical, while drilling at a high rate of penetration (ROP) through formations with inherent deviation
tendencies, without the aid of exotic and expensive active directional steering tools
Wellbore deviation issues in vertical sections can result from numerous factors; however, they are typically a result
of drilling through faulted zones, highly fractured formations and intervals with highly dipped formations. Smith
Bits' VertiDrill line of fixed cutter bits maintain a vertical trajectory or can correct wellbore inclination to vertical
without expensive directional tools.
The tendency to drill vertically, independent of formation effects, is achieved with VertiDrill's uniquely designed
cutting structure layout and bit geometry, which create “active” and “passive” cutting zones.
VertiDrill has no moving parts to wear out and no seals to leak. Since the VertiDrill can be run on a conventional
rotary assembly, vertical sections of the wellbore can be drilled without an expensive
directional assembly. Additionally, the bit does not require a vertical drilling system and
eliminates trips for well path correction runs.
VertiDrill's patented design allows for conventional rotary drilling with the appropriate
weight-on-bit (WOB) that produces the best ROP for the bit-formation combination. The bit
also provides for very efficient rock removal, resulting in longer life.
With VertiDrill's unique cutting structure and bit geometry, the bit inherently drills towards
the low side of the wellbore. In formations with severe dip angles, the bit maintains a
vertical wellbore as a result of the active and passive zones of the cutting structure.
Formation is drilled as the active zone of the bit engages the low side of the wellbore. As the
bit rotates to the high side of the wellbore, the active blade area disengages from the
formation and the bit's passive zone is then on the low side of the wellbore. Due to the bit's
unique layout and geometry, the passive zone of the bit does not engage the wellbore.
The result: the VertiDrill bit cuts the wellbore only when the active zone is engaged on the
low side of the wellbore. The bit's medium profile length improves side-cutting capability and its increased
diamond volume results in enhanced durability in abrasive applications. VertiDrill's relatively shallow cone design
minimizes formation resistance in the bit center and prevents the bit from deviating.
The bit's plural cutting structure layout optimizes performance in abrasive applications and increases drilling
efficiency. The bits can be tailored to optimize performance for a specific application with the number of blades, and
the cutter size and density are determined by the application's formation characteristics.
Smith's innovative engineering of VertiDrill bits lowers drilling costs by offering a proven alternative to expensive
directional drilling systems.
Drill Bits for Maintaining a Vertical Trajectory
15
SHAHEEN™
Smith Bits developed SHAHEEN PDC bits specifically to swiftly and surely attack hard carbonate formations unique
to the Middle East. The Shaheen, or peregrine falcon, is noted for being the fastest bird in the world in terms of its
hunting dive, achieving speeds in excess of 320 kilometers per hour. Likewise, SHAHEEN PDC bits have been
designed to provide unsurpassed speed in attacking difficult formations.
The key to achieving superior performance
in the face of the technical challenges posed
by the difficult-to-drill Middle East ® formations was Smith's use of IDEAS - the
Integrated Dynamic Engineering Analysis
System. By focusing IDEAS, the industry's
most advanced and accurate drill bit design
system, on the unique lithologies of the Middle East,
Smith Bits created the SHAHEEN line of PDC drill bits
that consistently outperform previous PDC bit designs.
By using the IDEAS bit design platform, Smith Bits design engineers can certify bit performance in Middle East
carbonates without going through the costly and time consuming trial-and-error of conventional bit design
processes. Whether the need is for improved ROP, greater durability, or specific directional behavior for today's
complex rotary steerable tools, Middle East operators are seeing both increased footage and faster ROP in
carbonate formations resulting from the improved dynamic stability of SHAHEEN PDC bit designs.
With SMITH, SHAHEEN and IDEAS, you get the winning combination that offers a better, customized Middle East
solution - the first time, every time.
Consistently Delivering Superior Performance in Difficult -to-Drill Middle East Carbonate Formations
SHAHEEN is designed with the specific characteristics required to effectively drill Middle Eastern Carbonates.
16
Some examples of Shaheen bits include:
MSi1016VHBPX
SDi616MHUBPX
MTi913WUETBPXC
MDi716LVPX
SSi916HMBPX
MDSi613LWBPX
Smith Bits' Kinetic bits are designed for superior performance when drilling at high rotary speeds through the
toughest, most abrasive formations. Kinetic bits have established world and field records for most footage drilled
and highest rate of penetration (ROP) in numerous regions throughout North America, Latin America, Europe,
Africa and the Middle East.
™KINETICDiamond Impreg Bits
Open face foroptimum clearing
Brazed in GHI
Cast in GHI
Application tuned impregnated body material
Central flow
Dedicated fluid port
Most Kinetic bits use strategically placed premium PDC
cutters in the cone area to improve drill-out capability and
maximize ROP. The cutters are backed up by the
impregnated matrix material for enhanced durability. TSP
inserts are positioned on the gauge to ensure that the bit
maintains a full gauge hole. In extremely abrasive
applications, TSP elements are also placed on the bit
shoulder for increased durability and enhanced wear
resistance in this critical area.
The bit designs incorporate innovative new cutting
concepts, including increased blade heights that make
placements of larger volumes of diamond material
possible. This results in increased nose and shoulder durability while retaining solid gauge protection in abrasive
applications. Increased blade height translates into more footage drilled than is attainable with conventional
impregnated drill bits.
Kinetic bits also feature custom approaches to impregnated bit design for the particular drive system being used
for a specific application. The bit profile is tailored to optimize performance whether the bit is run with a PDM or
turbodrill.
A highly efficient hydraulics configuration is also engineered into the Kinetic bit design. The bit uses a combination
of center flow fluid distribution and precisely placed ports to enhance bit cooling and to ensure efficient bit
cleaning. The Kinetic bit can effectively drill through mixed lithologies at optimal ROP, reducing the need to change
bits for the different formations encountered. The result is faster ROP, fewer trips and a lower total cost to the
operator.
Kinetic diamond impregnated bits set records for ROP and footage drilled.
Kinetic Bit Configurations
17
High performance when combined with turbodrills
Because of the inherent power and longevity advantages that a turbodrill
has over a PDM, which incorporates elastomers in the power section, the
Kinetic bit delivers particularly high performance when combined with
Smith Neyrfor's turbodrill. The bit's extended gauge, in conjunction with
the stability of the turbodrill, generates superior orientation capability;
excellent hole quality with API Class hole geometry; elimination of hole
spiraling; reduced parasitic rotary torque; and improved hole and log
quality. The turbodrill features a bit-shock dampening hydraulic system
and bit optimization without sacrificing directional control.
For drilling the hardest, most abrasive rocks in the world, let the record
show that there is no better combination than a Smith Bits Kinetic
diamond impreg bit run on a Smith Neyrfor turbodrill.
™KINETICDiamond Impreg BitsProprietary combination of ultra-hard materials
Kinetic bits are built with precisely engineered Grit Hot Pressed Inserts (GHI), premium PDC cutters, thermally
stable polycrystalline (TSP) diamond and proprietary diamond impregnated matrix materials. Each element is
chosen to optimize both durability and ROP.
GHI inserts consist of a proprietary combination of natural diamond stones and tungsten carbide matrix powder
tailored to specific material properties for the drilling application. GHI uses a proprietary granulation process that
ensures a more uniform distribution of the diamond material than is possible in the conventional pelletization
process. The resulting more consistent GHI is more durable, maintains its shape and drills faster for a longer
period. The individual GHIs are similar to small grinding wheels, taking a very small depth of cut with each bit
rotation. They continually sharpen themselves while drilling by grinding away the bonding material to expose new
diamonds. Hybrid designs, designated with an “H”, incorporate PDC, natural diamond and TSP material.
Kinetic bits can be tailored with different bonding materials and diamonds to match the formation being drilled and
the drive system used, making the bits ideal to exploit the higher rotational velocities possible with turbodrills.
Because the GHIs are raised to allow a greater flow volume on the bit face, Kinetic diamond impregnated bits are
able to drill PDC drillable shoe tracks and improve ROP in a wider range of applications extending the economic
application range of the bits.
Additionally, Kinetic bits are cost-effective in overbalanced applications where drilling with a conventional fixed
cutter or roller cone bit results in low ROP and reduced footage.
7-7/8” K705BPX6” K505TBPXX
6-1/2” K507TBPXC
Kinetic Nomenclature
K - Kinetic Line
K 5 0 3
Product Line Iteration
Type Size Availability
4-1/8” - 12-1/4”
6-1/2”, 8-3/8”, 8-1/2”, 8-3/4”,12-1/4”
4-1/2” - 8-3/4”
6”, 6-1/2”, 8-1/2”
6”
Blade Density (1 = Heavy, 9 = Light)
3-3/4”, 6”, 6-1/8”, 14-3/4”
6” - 12-1/4”Profile (3 = Round, 5 = Medium Parabolic, 7 = Long Parabolic)
8-3/8”, 8-1/2”, 12-1/4”
8-1/2”
14”
K503K505K507K703K705K707KH613KH813KH1013KH1213
H
H - Hybrid Cutting Structure
18
Standard Nomenclature
M/S - Matrix or Steel
M 1 6
M413M416M419M509M511M513M516M519M609M613M616M619M711M713M716M809M813M816M909M916M1609MD519MD611MD613MD616MD619MD813MD816MD819MD913MD916MD919MDi416MDi513MDi516MDi519MDi613MDi616MDi619MDi713MDi716MDi719MDi813
MDi816
Type Size Availability
Cutter Size
Standard PDC Bits
6
Blade Count
7-7/8”
6” - 7-7/8”
8-1/2”
3-3/4”
4-1/2”
4-3/4”, 4-7/8”, 6-1/8”, 6-1/4”, 7-7/8”
5-7/8” - 9-7/8”, 11-5/8”, 12-1/4”, 16”
6” - 9-7/8”, 12-1/4”
3-5/8”, 3-3/4”, 4-1/8”, 4-1/2”, 4-3/4”
6” - 8-1/2”, 11-5/8”, 12-1/4”
6-3/4” - 9-7/8”, 12-1/4”
7-7/8” - 17-1/2”
8-1/2”, 8-3/4”, 9-1/2”, 12-1/4”
6”, 8-3/8” - 12-1/4”
6”, 6-1/8”, 6-3/4”
6”, 7-7/8” - 9”, 12-1/4”
16”
4-3/4”, 5-7/8”, 6”, 6-1/2”
8-1/2”
5-7/8”
8-1/2”, 8-3/4”
8-1/2”, 12-1/4”
5-7/8”
6”, 6-1/8”
6”, 8-3/8” - 9-7/8”, 12-1/4”, 14-3/4”
8-1/2”, 9-1/2”, 12-1/4”, 17”
8-1/2”
6”, 6-1/8”, 8-1/2”, 9-1/2”, 12-1/4”, 16-1/2”
12-1/4”
8-1/2”, 12-1/4”
8-1/2”, 12-1/4”
i
i - IDEAS Certified
17-1/2” S519
Smith Bits' standard line of fixed cutter drill bits are the workhorse of the oilfield. These bits are designed to deliver
premium performance and excellent durability. The features, cutter types, cutter layout and blade geometry of
these bits are continuously being evaluated and improved to deliver value and drive down drilling costs. The
IDEAS Certified design process is your assurance that these bits will offer optimum performance in your specific
drilling application.
12-1/4”, 13-1/2”
6-1/8”
5-5/8”, 6-1/8”, 6-1/4”, 7-7/8”, 8-3/4”
6-1/8”, 8-1/2”
8-3/4”, 14”
6-3/4”, 8-5/8”, 8-1/2”, 9-1/2”, 9-7/8”
12-1/4”, 14-1/2”, 16”, 17-1/2”
5-7/8”
8-1/2”, 12-1/4”, 14-3/4”
8-1/2”, 10-5/8”, 12-1/4”, 14-1/2”
5-3/4”, 8-3/4”, 12-1/4”, 14-1/2”, 14-3/4”, 16-1/2”
8-3/8”, 8-1/2”, 10-5/8”, 12-1/4”,13-3/4”, 17-1/2”, 18-1/8”, 18-1/4”
Type Size Availability
6-3/4”
6” & 12-1/4”
8-1/2”, 10-5/8”, 12-1/4”, 13-1/2”14-3/4”, 16”, 17” & 17-1/2”
8-1/2” & 12-1/4”
12-1/4”
16”
8-1/2”, 12-1/4” & 17-1/2”
8-1/2”, 12-1/4” & 17-1/2”
14-3/4”
12-1/4”
16”, 17-1/2” & 26”
26”
16” & 17-1/4”
13-1/2”
8-1/2” & 12-1/4”
16”
13-1/2”
23” & 24”
17-1/2”
12-1/4”
8-1/2”
8-1/2” - 14-3/4”
12-1/4” Mi616
Matrix & Steel Fixed Cutter Bits
6-1/2”
6-1/8”, 6-1/4”, 6-3/4”, 7-5/8”, 7-7/8”
6-1/8”, 8-1/2”, 9-7/8”
6-1/4”, 6-1/2”, 7-7/8”, 8-3/4”
6-1/2” - 8-3/4”, 12-1/4”
8-3/4”, 9-7/8”, 12-1/4”
6-1/2”, 7-7/8”, 8-3/4”
7-7/8” - 9-7/8”, 12-1/4”
12-1/4”, 17”
6-1/8”
7-7/8” - 8-3/4”, 12”, 12-1/4”, 14-3/4”
6”
6-1/8” - 6-3/4”, 10-5/8” - 17-1/2”
12-1/4”, 17-1/2”
7-7/8”, 12-1/4”
12-1/4”, 14”, 16”
16”
12-1/4”
Mi413Mi416Mi419Mi513Mi516Mi519Mi613Mi616Mi619Mi713Mi716Mi811Mi813Mi816Mi913Mi916Mi919Mi1016S416S422S516S519
S522S613S616S619S716S719S816S819SD519SDi613SDi616Si419Si519Si613Si616Si619Si819
19
Natural Diamond Bits
D54
D66
D71
DST12
6-1/8”
4-5/8”, 4-3/4”
6-3/4”
5-7/8”, 6”, 6-1/8”, 6-1/2”
7-7/8”, 8-3/4”
Cutter Size Current Availability
6-3/4” D71 4-3/4” D66
Natural Diamond Nomenclature
ST - Sidetrack
D - Surface Set Diamonds
D S T 1 2
Smith Bits’ complete line of natural diamond bits can provide cost-effective drilling in a range of formations, from
medium-soft to extremely hard conditions. A variety of cutting structure profiles, with either feeder/collector or
radial flow hydraulic designs and a complete selection of diamond patterns and qualities, are available to match the
bit to the application.
Feature-for-feature, Smith Bits’ natural diamond bits
have proven themselves in wells worldwide, delivering
the lowest cost-per-foot and the highest degree of
accuracy and reliability.
Cube A Congo diamond, cube-shaped with fair abrasion and impact resistance.
West African - PremiumDodecahedron in shape with good impact resistance and excellent abrasion resistance.
CarbonadoA naturally occurring, polycrystalline diamond, irregular in shape. Excellent impact resistance and good abrasion resistance.
Congo Round - RegularA round monocrystalline diamond with a rough, textured surface. Fair abrasion and good impact resistance.
Diamond Types
XX - Formation Hardness(00 Harder / 99 Softer)
1-10 spc
1-10 spc
1-10 spc
1-10 spc
NATURAL DIAMOND
20
21
PDC Cutter TechnologySmith Bits maintains an aggressive internal R&D development program for PDC cutters with the goal of maximizing both wear and impact resistance. Engineers focus on continuous innovation in material properties, diamond layer configuration, and manufacturing processes and techniques which are the fundamental elements of producing a superior PDC cutter.
Smith is uniquely positioned to provide customers with the most choices for PDC cutter technology. Our Ultrahards Materials division designs and manufactures high-performance PDC cutters, and maintains state-of-the-art manufacturing facilities in Provo, Utah (MegaDiamond) and Scurelle, Italy (Supra Diamant). Smith Bits also continually evaluates and utilizes the best available technology from third party vendors.
With its team of scientists, researchers and engineers, Smith continues to develop new materials and technologies to provide ultra-hard products with ever-increasing performance and reliability. Our Advanced Materials laboratory provides the tools necessary for controlling raw materials, analyzing compositions and evaluating material properties. Sophisticated computer modeling and FEA (finite element analysis) systems assist the technical staff in designing products for maximum performance. As a result, customers are assured of superior cutter performance when running a Smith PDC bit.
Smith PDC Cutter Performance Improvement
Wear Resistance
Impact Resistance
The chart below shows the relative improvement in cutter properties for impact and wear resistance over the past five years. The significant increase in cutter performance is directly reflected in overall PDC drill bit performance gains that Smith Bits has attained during this period.
Smith Bits' position of PDC bit performance leadership is testimony to the success of our R&D efforts in cutter technology.
2003 - 2004 2005 - 2006 2007 - 2008
Relative WearResistance
Relative ImpactResistance
Grit Hot-Pressed Inserts (GHI) use a proprietary granulation
process that ensures a much more uniform distribution of the
diamond material than is possible in the conventional pelletization
process. This results in a more consistent GHI that will be much
more durable, maintain its shape and, as a result, drill faster for a
longer period of time.
The individual GHIs are similar to small grinding wheels, so they
take a very small depth of cut with each rotation of the bit. While
drilling, GHIs continuously sharpen themselves by grinding away
the bonding material to expose new diamonds. Smith customizes
the GHIs 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 on the bit face,
the new Smith Kinetic impreg bits can drill faster in a wider range of
formations, thus extending the application range for these bits.
GHI (Grit Hot-Pressed Inserts)
Insert Technology
The revolutionary Smith Bits GHI is more durable than conventional GHIs, and will drill faster for a longer period of time.
Uniform Diamond Distribution and Optimized Material Wear Rates
22
CFD
Efficient Hydraulics Increases Performance and Lowers Drilling Costs
Smith’s design engineers use computational fluid dynamics (CFD) to model the interaction of drilling fluids with the
bit and the wellbore. These complex algorithms enable the simulation of a wide variety of downhole conditions and
allow the engineer to evaluate the effects of various blade and nozzle configurations in order to optimize flow
patterns and improve the performance of the bit.
Smith Bits makes extensive use of this sophisticated technique to maximize the available hydraulic energy and
provide operators bits that will drill at the lowest possible cost per foot/meter.
23
Computational Fluid Dynamics (CFD)
Using CFD to visualize flow patterns provides designers with a reliable platform to analyze the effects of design modifications on bit performance.
CFD analysis can reveal any potential problems with flow patterns and allows designers to optimize the bit design for maximum performance.
B Feature Backreaming CuttersFeature: Backreaming cutters
Advantage: Strategic placement of cutters on the upside of each blade to allow backreaming in tight spots to reduce potential of "bit sticking” while pulling out of the hole
Benefit: Allows a degree of backreaming sufficient to condition a hole without major risk of gauge pad wear
C Feature Connection Not API StandardFeature: Non-standard connection, including box
connection
Advantage: Allows non-standard box connection for a given bit size; Shortest possible length between bit box and turbine or motor pin
Benefit: Provides stabilization, reduces hole spiraling and provides additional gauge protection
OPTIONAL FEATURES
24
D Feature DOG Sleeve (Drilling on Gauge)Feature: Dog Sleeve
Advantage: Mitigates hole spiraling
Benefit: Enhances BHA stability and helps maintain in-gauge wellbore
OPTIONAL FEATURES
E Feature (common to all bit types)Extended Gauge Length
Feature: Longer gauge than standard
Advantage: Provides a means of increasing bit stability and allows more area for gauge protection components
Benefit: Enhances stability and improves hole quality
H Feature Larger than Standard TFAFeature: Higher number of nozzles than standard
Advantage: Higher nozzle counts and/or added fixed ports to increase cleaning, cooling and cuttings evacuation with available hydraulic flows; Allows for higher flow rates with minimal increase in pump pressure
Benefit: Optimized ROP and bit life; Longer drilling intervals without need for tripping
25
I FeatureIF Connection
Feature: Replaces standard connection
Advantage: Allows the bit to conform to directional tools connection type
Benefit: Provides more flexibility in configuring a drilling assembly
OPTIONAL FEATURES
L FeatureLow Exposure
Feature: Cutter backing raised to minimize excessive depth of cut due to formation heterogeneity
Advantage: Reduces cutter loading
Benefit: Minimizes cutter breakage and extends bit life
K FeatureImpregnated Cutter BackingFeature: Diamonds impregnated in the matrix behind
the PDC cutters
Advantage: Limits the wear progress of PDC cutters
Benefit: Increased footage drilled in abrasive applications
26
M FeatureReplaceable Lo-Vibe Feature: Lo-Vibe inserts that can be replaced when
needed (wear, breakage, etc.)
Advantage: Limits excessive depth of cut and helps reduce torsional vibration
Benefit: Optimized ROP and bit life
OPTIONAL FEATURES
Q FeatureContains Fixed PortsFeature: Incorporates fixed ports
Advantage: Design employing fixed ports to optimize hydraulics in applications for which employment of nozzles compromise bit design because of space or similar limits; Provides additional cleaning of the cutting structure
Benefit: Optimized ROP and bit life
N FeatureFewer Number of Nozzles than StandardFeature: Lower than standard nozzle count
Advantage: Reduced nozzle count to best match drilling, formation, and hydraulic system capabilities. Reduces flow rate required to achieve an appropriate HSI; Avoids the use of numerous, smaller nozzles that can plug
Benefit: Optimized ROP and bit life; Longer drilling intervals without need for tripping
27
PX FeatureDiamond Enhanced Gauge Protection
Feature: Diamond enhanced gauge protection
Advantage: Thermally stable polycrystalline diamond (TSP) to provide extra protection to the gauge
Benefit: In-gauge hole and longer bit life; Longer drilling intervals without need for tripping
OPTIONAL FEATURES
PXX FeatureFull Diamond Gauge Pad onTurbine SleeveFeature: Full diamond gauge pad on turbine sleeve
Advantage: Diamond enhanced inserts to provide the greatest possible gauge protection in highly abrasive formations and underbalanced drilling
Benefit: In-gauge hole and long gauge life in extreme drilling environments; Longer drilling intervals without need for tripping
R FeatureRestrictor Plate in the Pin
Feature: Nozzle fitted in the pin of the bit in high pressure drop applications
Advantage: Splits pressure drop between nozzle in the pin and nozzles in the bit
Benefit: Allows installation of larger nozzles in the bit reducing nozzle velocity and bit body erosion
28
S FeatureShort Gauge Length
Feature: Short gauge length
Advantage: Reduced bit height to improve bit steerability for directional and horizontal applications; Reduced slide time and footage by achieving builds and turns more quickly
Benefit: Lower cost per foot, higher overall ROP
V FeatureTMLo-Vibe Option
Feature: Lo-Vibe option
Advantage: In applications in which bit whirl is a problem, the Lo-Vibe option improves bit stability and reduces potential for damage to the cutting structure by restricting lateral movement and reducing the effects of axial impacts.
Benefit: Optimized ROP and bit life. Long drilling intervals without need for tripping.
OPTIONAL FEATURES
T FeatureTurbine Sleeve
Feature: Turbine sleeve
Advantage: Turbine sleeves reduce vibration and hole spiraling in turbine applications. Sleeve lengths can be varied to best match a specific application.
Benefit: Optimized ROP and bit life. Long drilling intervals without need for tripping.
29
U FeatureContains 50 Series Nozzles
Feature: Contains 50 Series Nozzles
Advantage: Maximized adjustable TFA for smaller or heavier set designs
Benefit: High efficiency for cleaning, cooling and cuttings evacuation without sacrifice to the cutting structure that could compromise ROP or bit life
Y FeatureContains 30 Series NozzlesFeature: Contains 30 series nozzles
Advantage: Allows more freedom in cutting structure design, particularly in smaller bits with limited areas for placement of larger nozzles, (N60)
Benefit: High efficiency for cleaning, cooling and cuttings evacuation without sacrifice to the cutting structure that could compromise ROP or bit life
OPTIONAL FEATURES
W FeatureContains 40 Series NozzlesFeature: Contains 40 series nozzles
Advantage: Increase thread size for wear/erosion resistance
Benefit: Reduced pop-up force when tightening the nozzle
30
Z FeatureTSP on Leading Edge (Kinetic)
Feature: TSP diamond is placed on leading edge of blades
Advantage: Enhances durability in specific locations on the profile
Benefit: Increases wear resistance, ensures full-gauge hole and extends bit life
Fixed Cutter Bit NomenclatureProduct Line
PrefixDescription
i IDEAS certified design Di IDEAS certified directional designA ARCS & ARCS Advanced
V VertiDrill
S SHARC
C Carbonate
HOX Heavy Oil Series
M Matrix Body
S Steel Body
K Kinetic Impregnated Bit
H Kinetic Hybrid Bit
D Natural Diamond Bit
L 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 (<6 5/8") (pin down, box up)
Face Features Description
L Low Exposure
M Replaceable Lo-Vibe
V Lo-Vibe
Z TSP on Leading Edge (Kinetic)
K Impregnated Cutter Backing
Hydraulic Features
Description
H Higher Number of Nozzles Than Standard
N Lower Number of Nozzles Than Standard
Y 30 Series Nozzles
W 40 Series Nozzles
U 50 Series Nozzles
Q Fixed Ports
R Restrictor Plate
Nomenclature Identifies Blade Count/Cutter Size
Example: M616 = 6 Blades/16mm Cutters
Gauge Features
Description
E Extended Gauge Pad Length
S Short Gauge Pad Length
T Turbine Sleeve
D Dog Sleeve
B Back Reaming Cutters
PX TSP on Gauge
PXX Full Diamond on Turbine Sleeve
Connection Features
Description
C Non API Standard Connection
I IF Connection
31
Roller Cone Bits
8-1/2”
7-7/8”
8-3/4”
9-7/8”
Optimized TCI Bits Set New Standards of Performance
FHThe FH line of tungsten carbide insert bits (TCI) combines high rates of penetration with unmatched durability
and reliability. FH roller cone drill bits offer superior TCI bits for a wide variety of applications, and deliver a
lower cost per foot when drilling your well.
FH drill bits have patented insert and cutter geometries, and proprietary carbide materials that offer the
optimum combination to cause the rock to fail. Smith's unique rock mechanics laboratory gives unmatched
insight into the interaction between the cutting elements and the rock. Engineers use this sophisticated tool
to precisely monitor this interaction and optimize the bit design to allow the maximum mechanical energy to
be applied to the formation.
Cutting Structure
The FH bit's reliability is grounded on the latest generation bullet-shaped and dual dynamic seals. The FH seal
has undergone extensive finite element analysis (FEA) modeling in a laboratory environment, and the
laboratory results have been verified through extensive field testing in applications throughout North America.
The bearing in the FH series incorporates the latest evolution of the silver plated Spinodal™ friction bearing.
The proven properties of the proprietary Spinodal bearing material, along with the friction-reducing effects of
the silver combine to create a longer lasting, highly reliable bearing package.
Reliability
Smith was the first roller cone bit company to offer a truly “flexible” hydraulics
option. With the introduction of Flex-Flo™ the industry is no longer forced to use
hydraulic configurations that are not optimized for specific applications. Utilizing
state of the art computational fluid dynamics software, and our in-house bit flow
visualization system, led to the application specific options found in Flex-Flo. The
Flex-Flo options of S-Flo, X-Flo and V-Flo allow operators to choose the hydraulic
configuration most effective for the specific application being drilled (see page 41).
Hydraulics
2 F H
FHDesignation
XX - Cutting Structure
FH Nomenclature
8-3/4” FH28GVPS
12-1/4”
i 8
i - IDEAS Certified
1 33
FHi20, FHi21, FHi21B, FHi23, FHi23U, FHi24Y, FHi26, FHi28FHi30, FHi35, FHi38Y, FH40, FHi40, FH43Y, FHi45, FH50, FHi50
FH23, FHi28, FHi28W, FH30, FH35, FH40, FH45, FH50, FHi90Y
FH16B, FH16H, FHi18B, FH20, FHi20, FHi21B, FHi21UB FHi23B, FHi23U, FHi25, FHi25B, FH28, FHi28, FHi29, FHi30 FHi31, FH32, FHi35, FHi37HY, FHi38Y, FHi40, FH43Y, FH45 FHi50
FH23, FH28, FH30, FH35, FH45, FH50HY
FH24Y, FH50
Protecting the bearings of a roller cone bit as it cuts its way through hot, high-pressure rocks while immersed in
corrosive drilling and formation fluids is perhaps one of the most
challenging sealing environments in the world.
The Gemini Dynamic Twin Seal System is the industry leader in
durability and reliability. Since its introduction, The Gemini System
has undergone a continuing regimen of improvements in both
materials seal profile. The system consists of a primary seal that
protects the bearings and a secondary seal that protects the primary
seal. The proprietary dual material primary seal combines a highly
wear resistant dynamic face elastomer and a softer energizing
material that exerts a consistent, but not excessive, contact pressure.
This “bullet” shaped primary seal has a large cross sectional profile to
provide maximum protection for the bearing.
The secondary seal is also made from a mix of patented fabrics and is designed to guard against abrasive
particles in the well bore fluids coming into contact with the bearing seal. A proprietary thermoplastic fabric ®reinforced with Kevlar is positioned on the seal's dynamic face, embedded in an elastomer matrix. The fabric
provides resistance to wearing, tearing, and heat damage, as well as a barrier to abrasive elements in well bore
fluids. 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 weight and pressures.
The Gemini Dynamic Twin Seal System is available in a wide range of sizes and types of roller cone bits.
GF15B, GF20, GF40B, GF45YB, GFi50YB
Dynamic Twin Seal System
GF08, GF10, GF15, GF15D, GF20, GF20D, GF25, GF25Y, GF30GF30Y, GF40, GF40H, GF40YB, GF45Y, GF45HY, GF50Y, GF65YGF80Y
GF10, GF15, GF40
GF20, GF21, GF45, GFVH
GeminiTwin Seal System
GEMINI
8-1/2”
11-5/8”
8-3/8”
8-3/4”
9-1/2”
Gemini Nomenclature - Gemini bits incorporate a G in the prefix of the bit name.
GF20
12-1/4”
G04B, G04BD, GF05B, GF05BD, GF05W, GF10, GF10BDGF10HB, GF10HUB, GF15B, GF15BD, GF15HBD, GF20BGF20BD, GF20HB, GF26U, GFi28B, GF30B, GF30BD, GFi35BGF37U, GF37Y, GF47Y, GFi45, GGH+, MGGH+
17-1/2” G02B, G10B, G10T, G15B, G28B, G30B, GGH+
16” G10B, G10BD, G18D, GGH+, MGGH+
14-3/4” G10B, G25, G25W
24” G08B
26” G08B
8-1/2” GF40H
GF158-5/8”
34” MGG
34
12” GF20
23” G08B, G12B
Shamal Typhoon is Smith Bits’ newest roller cone drill bit technology developed specifically for the unique
challenges of Middle East larger diameter drilling applications. Typhoon hydraulics, innovative insert geometries,
and the latest carbide technology are targeted specifically at drilling
the hard carbonates of the Middle East, quickly with the utmost
durability, and provide a complete high performance package. IDEAS,
the industry's most advanced drill bit design system, ensures that all
these elements are integrated to attain optimum performance.
SHAMALThe Power and Performance of the Perfect Storm
Typhoon™
Shamal Typhoon bits incorporate three Vectored Extended (VE) nozzles and three Dome Jet (J3) inner nozzles to apply maximum hydraulic energy to the bottom of the wellbore which enhances cuttings removal and increases ROP.
16”
17-1/2”
28”
22”
GSi01B, GSi03B, GSi06B, GSi06UB, GSi12BGSi12UB, GSi15B, GSi18B, GSi20B
GSi01B, GSi03B, GSi12B, GSi18B
GS18B, GS18U, GS18UB
GS12B, GS12UB
Typhoon Hydraulics uses sophisticated computational fluid dynamics
(CFD) analysis techniques to evaluate fluid flow and ensure that flow is
optimized to clean the cones, remove cuttings more efficiently and
ensure that the cutting structure is always drilling virgin formation.
Typhoon Hydraulics utilizes both Vectored Extended (VE) nozzles and
Dome Jet (J3) nozzles to offer the optimum hydraulic solution for the
individual application.
Vectored Extended (VE) nozzles precisely direct the fluid flow to the
leading edge of the cones while the Dome Jet (J3) nozzles direct the
fluid flow toward the intermesh area between the cones rather than
directly at them. The combined effect of these six precisely oriented
nozzles is a flow pattern which creates significant improvements in
the path and velocity of the drilling fluid. This optimizes cutter
cleaning and the displacement of cuttings off-bottom and up the
drillstring and results in maximum ROP.
With the capability of providing more options for hydraulics
programs, Shamal Typhoon gives Smith's design engineers the tools
to create the best configuration for the customer's individual
application. The result is a bit that offers superior performance no matter what the drilling challenge.
Typhoon hydraulics are currently available for bits with outside diameters (O.D.) of 16” and larger.
16” GSi12BVEJ3
1 35
The Shamal TNG product line incorporates a range of tungsten carbide insert bits developed with direct input from
leading Middle East operators to maximize performance in the hard carbonates found throughout the region, and
Shamal TNG bits are now successfully drilling carbonate formations around the world.
Shamal TNG bits use a range of proprietary coarse carbide grades which are designed to combat heat checking and
subsequent insert chipping and breakage, which are the primary dull characteristics in the Middle Eastern
carbonates. Incorporating unique cone layouts and insert geometries, the Shamal TNG product line is providing
superior ROP and durability both in the Middle East and in other challenging applications throughout the world.
Shamal Nomenclature
12-1/4” GFS04B
Designed for Drilling in Carbonate Formationsin the Middle East........And Beyond
Bearing Prefix
Shamal Feature
G S 0 5
XX - Cutting Structure
SHAMAL TNG
8-1/2”
12-1/4”
14-3/4”
16”
17-1/2”
23-1/2”
24”26”
28”
22”
12”
GFS05B, GFS06, GFS06H, GFS15, GFS30, MFS04MFS10T, MFS20B
GFSi01, GFS04B, GS04B, GFS05B, GFS05UBGS05B, GFSi06, GFS10B, GS10B, GFS11YGFS15B, GS15B, GFS20B, GFS20UB, GFS26GFS30
GS10B
GS04B
GS04B, GS18BGS04B, GS18
GS18, GS18B, GS18U
GS08, GS12B, GS12UB, GS12SD
GFS28HB
i
i - IDEAS Certified
15” GS10B15-1/2” GS10
GS03B, GS05B, GS10B, GS18B, GS18UB, GS20BGS18UB, GS20B, GS20BD, GS26, GS30
GS03B, GS05B, GS05BD, GS10B, GS10BD, GS18
36
The Xplorer line of tungsten carbide insert roller cone bits is the result of a systematic engineering effort to
produce a complete line of application-focused bits designed with the sole objective of improving drilling
performance in slim holes. The Xplorer line covers the application range from very soft formations to ultra hard
formations with bits that provide consistently superior performance.
Xplorer Nomenclature
2 0
12”
Forgings
Even the most demanding
directional program is achievable
with ultra short leg forgings that
maximize steerability at extreme
build angles. The forging design also
maximizes the strength of the
chassis and meets the hydraulic
demands of today's dril l ing
programs.
Bearings
To handle the high rotation speeds typically seen in the formations in
which slim hole bits are used, a dual material Bullet™ seal system is used
for soft formation insert bits (IADC 4-1-7X to 5-4-7Y). This seal system
reduces seal wear while at the same time limiting temperature build-up
through the use of matched, dual elastomers.
For harder formation Xplorer bits (with IADC codes 6-1-7X and higher), a
rotary “O” ring seal with optimized properties is used. This significantly
increases the wear resistance of the seal compared to conventional HSN
materials. The use of this enhanced “O” ring seal builds on Smith Bits’
tradition of providing market leading bearing performance in hard
formations.
3-7/8” XR30Y
Application-Focused Premium Slim Hole Bits
Cutting Structures
Individual cutter layouts have been developed specifically for Xplorer
bits, as well as a complete range of inserts, insert grades and geometric
enhancements. Features such as Ridge Cutters™ stop the formation
from wearing against the cone shell. This significantly reduces cone shell
wear and associated insert loss as well as allowing the main cutting
structure to cut more effectively.
X R
Xplorer Designation
XX - Cutting Structure
XPLORER
6-1/2” XR20T 4-1/8” XR30
4-1/2” XR30
4-5/8” XR30
4-3/4” XR15, XR20, XR30, XR30Y, XR40Y, XR50, XR50YXRi15, XR30
5-1/2” XR20W, XR30, XR30W, XR30Y, XR40Y
5-5/8” XR15, XR30T
5-7/8” XR15T, XR20T, XR30T, XR40Y, XR50Y, XR50YD
6” XR10T, XR12, XR15T, XR20HT, XR20T, XR30T, XR30TY, XR40, XR40YXR40YD, XR45Y, XR50, XR50W, XR50Y, XR65Y, XR70Y, XR70YD, XRH40Y
6-1/8”XR10T, XR15T, XR15W, XR20HT, XR20T, XRSi20, XR20W, XR25, XR25WXR30T, XR30TY, XRi30, XRi30W, XRi35, XR38, XR40, XR40Y, XR50, XR50WXR50WY, XR50Y, XR60Y, XRi65Y, XR68Y, XR70Y, XR80Y, XR90Y
3-3/4” XR20Y
XR20T, XR20W, XR30T, XR30Y, XR40, XR40Y, XR40YA, XR50, XR50Y,XRi356-1/4”XR15T, XR20T, XR30D, XR30T, XR30TY, XR40, XR40Y, XR40YA, XR45WXR50, XR50WY, XR50Y, XR68Y, XR70Y, XR90Y
6-1/2”
XR10T, XR25T, XR32T, XR32W, XR40, XR506-3/4”
i
i - IDEAS Certified
4-7/8”
1 37
Expanding the Performance Platform
XPLORER
Xplorer Expanded milled tooth drill bits are specifically designed to drill soft formations with exceptional ROP and
reliability. Xplorer Expanded products incorporate the latest developments from Smith Bits’ design engineers in
the Bit Design and Materials Engineering group.
Xplorer Nomenclature
+
TMFlex-Flo
The Xplorer Expanded bits are equipped with the Flex-Flo Adaptive Hydraulics System to provide customers with
the widest range of options for maximizing ROP and ensuring effective hole cleaning in any application. With the
choice of S-Flo, V-Flo or X-Flo, customers can select the best hydraulic configuration for the specific application
(See page 41).
Hardfacing
Smith Bits ongoing investment in materials technology
gives the Xplorer Expanded bits the added durability of the
proprietary MIC2™ hardfacing material. This ultra wear
resistant material, which is the result of the evolution of
several generations of proven hardmetal technology,
allows the Xplorer Expanded bits to drill at high ROP for a
XR+
Cutting Structures
The cutting structure of the Xplorer Expanded delivers
maximum possible shearing and scraping action in the
softer formations encountered in mill tooth applications.
The configuration is designed to provide a fast ROP while
ensuring maximum durability.
X R
Xplorer Designation
XX - Premium Milled Tooth Cutting Structure
Expanded
Seals & Bearings
All Xplorer Expanded bits 8-½” and larger in diameter have
the Gemini Dynamic Twin Seal System, the industry's best
protection for bearings. The Spinodal journal bearing
provides the ultimate in reliability and durability for the
most demanding applications. (Sizes 13-½” - 36”
incorporate Smith's premium sealed roller bearings).
20” XR+CVPS
4-1/2”, 4-3/4”, 4-7/8”, 5”, 5-1/2”, 5-5/8”, 5-3/4” 5-7/8”, 6”, 6-1/8”, 6-1/4”, 6-1/2”, 6-3/4”, 7-7/8”8-3/8”, 8-1/2”, 8-3/4”, 9-1/2”, 9-7/8”, 10-5/8” 11-5/8”, 12-1/4”, 13-1/2”, 13-3/4”, 14-1/2”, 14-3/4” 15”, 15-1/2”, 16”, 17”, 17-1/2”, 18-1/8”, 18-1/2” 19-1/4”, 20”, 21-3/4”, 22”, 23”, 24”, 26”, 31” 32-1/4”, 32-3/8”, 33”, 36”
38
Two Cone Technology for More Aggressive Roller Cone Designs
TCT™
+T C
TCTDesignation
XX - Premium Milled Tooth Cutting Structure
TCT Nomenclature
8-1/2” TCTi+
9-7/8” TCTi+
12-1/4” TCTi+, TCT11, TCT12
T 6-1/2” TCTi+
8-3/4” TCTi+, TCT20, TCT37Y
16” TCT+17-1/2” TCT+, TCT10W
i
i - IDEAS Certified
9-7/8” TCTi+
1 39
7-7/8” TCTi+20
Smith Bits’ 21st century two-cone drill bits were designed using the proprietary IDEAS drill bit design platform.
IDEAS' dynamic modeling capabilities mean that its two-cone bits are designed, evaluated and tested in a virtual
setting to reduce vibration, enhance the bit's stabilization and increase ROP.
Smith Bits design engineers modeled and analyzed the performance of numerous cutting structure designs. As a
result, Smith's two-cone bits have a cutting structure layout that 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. The bits also benefit from current technology for enhanced insert geometries and
the latest carbides and hardfacing materials.
Smith's two-cone bit design incorporates computational fluid dynamics (CFD)
algorithms to ensure optimal nozzle positioning. The bit designs can utilize five
nozzles, four outboard and one center jet. Smith's field proven V-Flo™ (Vectored
Flow) nozzle configuration optimizes cone cleaning and cuttings evacuation (see
page 41).
The TCT’s five nozzles are precisely positioned and directed for increased
impingement pressure and improved penetration rates resulting from excellent
cutting structure cleaning and efficient cuttings removal. Additionally, the two-
cone bit's five-nozzle configuration significantly increases available options for
directing the nozzles compared with a three-cone bit configuration that utilizes
three nozzles.
An extensive new forging design was developed for the two-cone bit as a result of
IDEAS simulation. Smith's two-cone bits are designed with four points of
stabilization to reduce vibration. The lug pads and leg-backs are protected by
tungsten carbide inserts to stabilize the bit and ensure a full-gauge wellbore. The
lug pad and leg-back placement, along with the forging's geometry, ensures
reduced vibration, longer bit life and higher ROP.
®The bit's durability and reliability are assured with its Gemini Dynamic Seal System, which utilizes a pair of seals
working together to provide the most reliable and robust sealing mechanism available in roller cone bits. They
maintain seal integrity in the harshest environments, including high RPM, high weight, high dogleg severity, high
mud weights, and high temperature, high pressure conditions.
Applying 21st century technologies, Smith Bits' two-cone drill bits can knock-out tough drilling situations.
Smith Bits' standard line of journal and roller bearing bits deliver premium performance. Our standard bits are
the focus of an ongoing product improvement effort which enhances existing designs and integrates new
materials technology. The features, components, and performance of these bits are continuously improved in
order to play an aggressive role in driving down drilling costs.
Among the features and materials incorporated into the standard product offering are the Spinodal journal
bearing, a new bearing lubricant, the Flex-Flo Adaptive Hydraulics System, MIC2 hardfacing, diamond
enhanced inserts, coarse carbide inserts and relieved gauge inserts.
Bearing Prefix
Standard Nomenclature/TCI Inserts Bits
2 F 1
Milled Tooth, TCI and Open Bearing Bits
OFH, OFM
XX - Cutting Structure
STANDARD PRODUCTS
FDTFDS+, FI18, F26Y, F27Y, F27iY, F30Y, F37HYFI39HY, F45H, F47HY, F47YA, F49YA, F57YF59HY, F67Y, F80Y, F85Y, F90Y
MFDGH, SVH, F37Y, F57Y
F40YA, F50YA
FDS+
F37, F47Y, F67Y, F85Y, F90Y
DSJ
MSDGH
DSJ, MSDGH
F20, F20Y, F27Y, F37Y, F47Y, FDS
3-3/4” - 6-3/4”
7-1/2”
7-7/8”
8-3/8”
8-7/8”9-1/2”
10-5/8”
12-1/4”
17-1/2”
22”
23”
11”
Bearing Prefix
Standard Nomenclature/Milled Tooth Bits
H F VHeel Inserts
Medium to Hard Formation Type
F3014-3/4”
MSDGH28”
12-1/4” FVH
8-3/4” F12
40
FDGH, FVH6”
F10, F37HY, F37Y, F47HY, F57Y, F67Y, F80Y, F85YFDGH, FDS+, MFDGH
8-1/2”
FDS+, F12V, F26Y, F27iY, F30T, F37HUY, F37HYF39HY, F40YA, F46HY, F47HY, F47YA, F50YA F59Y, F67Y, F80Y, F85Y, F90Y
8-3/4”
FDS+, F10B, F37Y, F47HY, F59Y, F67Y, F80Y F85Y, F90Y
9-7/8”
F30, F47Y, FDGH, MSVH11-5/8”
F25Y, F37Y, F40, F47YA, F57, F67, F80Y, F90YFDGH, FDS+, FDT
MSDGH17”
MSDGH20”
DSJ, MSDGH26”
Smith Bits roller cone bits offer the utmost in hydraulic configuration flexibility and performance . Due to the wide
range of drilling applications around the world, there is no one hydraulics configuration that works best for every
situation. Each application has its own requirements for the three primary bit hydraulic functions of cutting
structure cleaning, bottom-hole cleaning, and cuttings evacuation. With Flex-Flo, Smith offers the ideal option for
each situation.
(Standard Flow) - In applications with high percentages of solids in the mud and in abrasive formations, S-Flo uses three identical nozzles to allocate hydraulic energy to prolong bit life.
®S-FLO(Cross Flow) - The many variations of X-Flo allocate available hydraulic energy to improve penetration rates through both cone cleaning and dramatically increased impingement pressure needed for ultimate bottom hole cleaning.
®X-FLO
(Vectored Flow) - V-Flo uses three directed nozzles to allocate available hydraulic energy for improved penetration rates through superior cutting structure cleaning and efficient cuttings evacuation.
®V-FLO
To assist in hydraulic selection, typical applications have been divided into four formations zones, ranging from
very soft to very hard. Within each of these zones, the relative importance of each of the three bit hydraulic
functions is ranked. Bit hydraulic performance can be enhanced through the use of this hydraulic road map, and
refined to your specific application by consulting your local Smith Bits representative.
TMFlex-Flo Adaptive Hydraulics
ZONE 1
Very soft and/or sticky
formations that
generate very large
volumes of cuttings
with Milled Tooth bits
and very soft TCI bits
ZONE 2
Low strength
formations that
generate large cuttings
volumes and drill with
soft TCI bits
ZONE 3
Medium strength
formations that generate
moderate cuttings
volumes with medium-
hard TCI bits
ZONE 4
High strength
formations that
generate low cuttings
volumes with hard TCI
bits
Cutting Structure Cleaning
Bottom-Hole Cleaning
Cuttings Evacuation
Soft/StickyHard/Abrasive
Hydraulic Function vs. Formation
Hydraulic F
unctio
n N
eed
1 41
Superior Flexibility and Performance
Typhoon Hydraulics uses sophisticated CFD analysis techniques to evaluate fluid flow and ensure that flow is
optimized to remove the cuttings more efficiently and that the cutting structure is always drilling virgin formation.
Typhoon Hydraulics utilizes both Vectored Extended (VE)
nozzles and Dome Jet nozzles to offer the optimum hydraulic
solution for individual larger hole diameter application.
Vectored Extended (VE) nozzles precisely direct the fluid flow
to the leading edge of the cones to provide the most efficient
cleaning.
The Dome Jet (J3) nozzles direct the fluid flow toward the
intermesh area between the cones rather than directly at
them. The combined effect of these six precisely oriented
nozzles is a flow pattern which creates significant
improvements in the path and velocity of the drilling fluid.
This improves cone cleaning, optimizes the displacement of
cuttings off-bottom and up the drillstring and results in
maximum ROP.
With the capability of providing more options for hydraulics
programs, Shamal Typhoon gives Smith's design engineers
the tools to create the best configuration for the customer's
individual application. The result is a bit that offers superior
performance no matter what the drilling challenge.
Typhoon hydraulics are available in bits with a diameter of 16” and larger.
Unmatched Versatility
42
Typhoon Hydraulics
Shamal Typhoon bits incorporate three Vectored Extended (VE) nozzles and three Dome Jet (J3) inner nozzles to apply maximum hydraulic energy to the bottom of the wellbore, which enhances cuttings removal and increases ROP.
CFD analysis allows Smith’s engineers to optimize available hydraulic energy to maximize ROP.
Smith Bits’ many insert geometries and material options make
possible the optimization of bit characteristics for specific target
applications. The development of insert geometries, along with
diamond and tungsten carbide materials optimization, is a key
focus of Smith’s research which means new, performance
enhancing features are constantly being proven and
incorporated into new and existing bit designs. Our research
and development is relentlessly targeted to create innovations
that lower drilling costs.
Insert Options
Smith Bits’ engineers can optimize insert materials to suit individual
applications. Insert material grades are not tied to a particular design
platform, rather they are matched to application requirements to maximize
performance flexibility, reliability and durability. Extensive research
resources are dedicated to continually developing carbides that are tailored
to specific applications. The work done with coarse carbides is an example of
this effort. These inserts offer a new level of performance in meeting the
drilling challenges of the world’s most demanding applications.
Geometry Choices
Smith was the first company to offer diamond enhanced inserts
in roller cone bits and remains the performance leader in this
technology. Today, diamond inserts can be used in various
areas of the bit, based on the needs of a particular application.
Diamond inserts can be used on heel rows, the gauge rows, as
every insert on all three cones, and/or on the bit leg, as the
situation requires. The use of diamond inserts helps ensure
maximum durability in the most challenging applications.
Diamond Choices
Material Choices
Smith pioneered the use of specific insert shapes in 1995. Since then we have used a number of proprietary tools
to determine optimum insert geometry for given bit designs. Among these insert geometries are conical, chisel, ®the Dog Bone , Incisor™ and Asymmetric Conic Edge (ACE) inserts.
The Dog Bone insert, initially used in the Shamal product line, is a case in point. Here a combination of toughness
and aggression has been designed to drill strong, non abrasive carbonates and also achieve higher ROPs in
interbedded clays and sands. The new Shamal Typhoon uses the DogBone along with the Incisor, ACE and
conventional chisel inserts to enhance the performance improvements provided by Typhoon hydraulics. The ACE inserts’ unique geometry is a hybrid of the conical and chisel insert. It has an offset conical top for
increased strength, and a flatter leading side to enhance scraping. This proprietary asymmetric design is highly
resistant to breakage and impact damage, yet more aggressive and effective in softer formations than a standard
conical insert.
Inserts
Coarse Carbide Microstructure
Diamond Enhanced Insert
1 43
Incisor DogBone ConicalChiselACERelievedGauge Chisel
B FeatureBinary Gauge ProtectionFeature: Small, semi-round top inserts positioned
between primary gauge inserts
Advantage: Smaller inserts to improve wear resistance
Benefit: Improved bit gauge durability and longer, in-gauge, bit runs
BD FeatureDiamond Enhanced Insert Binary Gauge Protection
Feature: Diamond enhanced semi-round top inserts positioned between primary gauge inserts
Advantage: The BD inserts to provide extreme wear resistance
Benefit: Improved gauge durability and longer, in-gauge bit runs
D FeatureDiamond Enhanced Gauge Row InsertsFeature: Diamond enhanced gauge inserts
Advantage: Diamond enhanced inserts to significantly lower gauge row wear and breakage rates and providegreater resistance to wear in highly abrasive applications
Benefit: High quality, full gauge well bore over significantly longer intervals than bits employing tungsten carbide gauge inserts
OPTIONAL FEATURES
44
DD Feature100% Diamond Enhanced Cutting Structure
Feature: 100% diamond enhanced cutting structure
Advantage: Premium cutting structure for drilling very abrasive formations efficiently, over longer runs, with lower WOB
Benefit: High ROP and extended bit life
G FeatureSuper D-Gun™ Cone Protection
Feature: Super D-Gun cone protection
Advantage: A hard, tungsten carbide based coating applied to cone shells to make them unusually resistant to abrasion and erosion; Ideal for applications in highly abrasive formations that generate large volumes of cuttings; Helpful in abrasive conditions with inefficient hole cleaning such as high angle, directional and horizontal applications
Benefit: Increased bit life, longer bit runs and improved insert retention
1 45
OPTIONAL FEATURES
OD FeatureDiamond Enhanced Heel Row InsertsFeature: Up to 50% diamond enhanced heel row inserts
Advantage: Diamond enhanced inserts to resist abrasive wear and impact damage better than tungsten carbide; Longer gauge cutting structure life and protection for lower leg and bearing seal areas
Benefit: Long intervals of high quality, full gauge hole
OD1 FeatureAll Heel Row Inserts Diamond Enhanced
Feature: 51% - 100% diamond enhanced heel row inserts
Advantage: Heel cutting structure is designed for the most abrasive environments; Longer gauge cutting structure life and protection for lower leg and bearing seal areas in highly abrasive, high compressive strength formations
Benefit: Longer intervals of high quality, full gauge hole (Increased life over 50% DEI heel insert structures)
SD FeatureShaped Diamond Gauge InsertsFeature: 100% shaped diamond enhanced gauge inserts
Advantage: Shaped geometry to create a more aggressive cutting structure and maximizes ROP
Benefit: High quality, in-gauge hole for the longest possible intervals in highly abrasive environments
46
OPTIONAL FEATURES
T FeatureTungsten Carbide Trucut™ Gauge Protection
Feature: Tungsten carbide Trucut gauge protection
Advantage: A twin gauge element system composed of an aggressive, near-gauge insert to drill the near-gauge and borehole corner with reduced scraping action, and semi-round top, on-gauge inserts that provide finish cut to gauge; Trucut gauge inserts less highly stressed than conventional gauge inserts with a much lower stress to improve gauge durability and integrity
Benefit: Extended bit gauge life for long intervals of quality, in-gauge hole
TD FeatureDiamond Enhanced Trucut™ Gauge ProtectionFeature: Diamond enhanced Trucut gauge protection
Advantage: Trucut gauge configuration in which diamond enhanced, semi-round top, rather than tungsten carbide, on-gauge inserts provide finish cut to gauge; Suitable for more abrasive environments; More durable than standard Trucut gauge configuration
Benefit: Extended bit gauge life for long intervals of quality, in-gauge hole
L FeatureLug Type Leg Back ProtectionFeature: Lug type leg back protection
Advantage: Shaped steel pads, welded to the upper leg back with flush-set tungsten carbide or shaped diamond enhanced inserts to provide leg protection and bit stabilization; Helps prevent bit whirl and helps prevent differential wear between individual bit legs that can overload individual cone cutting structures and bearings
Benefit: High quality wellbore and extended bit life
1 47
OPTIONAL FEATURES
PD FeatureDiamond Enhanced Leg Back ProtectionFeature: Diamond enhanced leg back protection
Advantage: Strategically placed semi-round top diamond enhanced and tungsten carbide inserts to improve leg protection against wear; Tight, overlapping pattern to help prevent grooving of leg backs; More wear resistant than [tungsten- carbide only] leg back protection configurations
Benefit: Extended bit life in extremely abrasive environments
PS FeatureSemi-Round Top Tungsten Carbide Insert Leg Back Protection
Feature: Leg back protection
Advantage: Strategically placed semi-round top carbide inserts to improve leg protection against wear; Tight, overlapping pattern to help prevent grooving of leg backs
Benefit: Extended bit life in abrasive environments
R FeatureSemi-Round Top Tungsten Carbide Insert Stabilization & Leg Back ProtectionFeature: Stabilizing leg back protection
Advantage: Cluster of semi-round top tungsten carbide inserts located on the upper leg section and extending to near full gauge and to stabilize the bit
Benefit: Enhanced wear protection and improved bit stability
48
OPTIONAL FEATURES
C FeatureCenter Jet Feature: Center jet installed
Advantage: Accepts suitable center nozzles to enhance cone cleaning and hydraulic flow patterns across the bit cutting structure
Benefit: Clean, efficient cutting structure in high cuttings volume and/or sticky formations
J3 Feature (Dome Jets)(Available for 16” and larger bits)
Feature: 3 nozzles positioned inboard of conventional roller cone nozzle position
Advantage: Flow directed toward the intermesh area between the cones to enhance cone cleaning andallow maximum ROP
Benefit: Increased cone cleaning to prevent bit balling
1 49
V Feature™V-Flo Nozzle Configuration
Feature: V-Flo hydraulic configuration
Advantage: Jets directed at the leading side of the following cone for maximum cleaning; Enhanced bottom hole cleaning through efficient cuttings lift and establishment of a strong, upward helical flow
Benefit: Maintains a clean cutting structure in soft and sticky formations
OPTIONAL FEATURES
Standard Diffuser
VE Feature(Available for 12-1/4” and larger bits)Feature: Extended vectored nozzle sleeve
Advantage: Angle of nozzle is precisely oriented to optimize cone cleaning and provide maximum ROP
Benefit: Vectored extended nozzles precisely direct the fluid flow to the leading edge of the cones to provide the most efficient cleaning
50
OPTIONAL FEATURES
Rock Bit Nomenclature
1 51
Bearing/Seal
Identifier &
Product Line
Prefix
Applies To: Refers To: Description
D All Bearing/Seal Non-sealed (open) bearing
S All Bearing/Seal Single seal, sealed roller bearing
F All Bearing/Seal Single seal, sealed friction bearing
MF All Bearing/Seal Single seal, friction bearing motor bit
M All Bearing/Seal Single seal, roller bearing motor bit
K All Bearing/Seal High temperature seals (geothermal applications)
G All Product Line Gemini®, twin seal, roller bearing
GF All Product Line Gemini®, twin seal, friction bearing
XR All Product Line Xplorer® (Milled Tooth bits up to 36"; Insert bits up to 6.75")
TCT All Product Line TCT™ bits, Two-Cone Technology
FH TCI Product Line FH bits, single seal, sealed friction bearing
S TCI Cutting Structure Shamal®
or Shamal Typhoon design
i All IDEAS IDEAS certified design (lower case - 'i')
+ MT Cutting Structure Milled tooth designator / Premium cutting structure
DS MT Cutting Structure Soft type (IADC 1-1-X) - applicable to 'FDS' bits only
DG MT Cutting Structure Medium type (IADC 1-3-X) - does not apply to Gemini
S MT Cutting Structure Soft type (formerly DS) - 'D' and 'G' products only
T MT Cutting Structure Medium soft type (formerly DT)
G MT Cutting Structure Medium type (formerly DG) - 'D' and 'G' products only
V MT Cutting Structure Medium hard type (formerly V2)
S MT Cutting Structure Premium self sharpening hard facing
H MT Carbide Gauge Non premium bit - heel inserts
B TCI Carbide Gauge Binary carbide gauge
H TCI Carbide Gauge Heavy set gauge design (count and or grade)
T TCI Carbide Gauge Trucut gauge (carbide material on both off-gauge and gauge)
00-99 TCI Cutting Structure Insert bit numeric range (00 Softest - 99 Hardest)
Product Suffix Applies To: Refers To: Description
I TCI Cutting Structure Inclined chisel on gauge (upper case - 'I')
W TCI Cutting Structure Softer than standard insert grades
Y TCI Cutting Structure Conical insert cutting structure
A All Cutting Structure Air application bit
N All Size Nominal gauge diameter
Feature Applies To: Refers To: Description
TD TCI Diamond Gauge Trucut diamond inserts (diamond on gauge; carbide on off-gauge)
SD TCI Diamond Gauge Shaped diamond gauge and Diamond heel (20% to 50%)
SD1 TCI Diamond Gauge Shaped diamond gauge and Diamond heel (51% to 100%)
D TCI Diamond Gauge SRT diamond gauge
OD All Diamond Heel Diamond heel, (20% to 50% diamond)
OD1 All Diamond Heel Diamond heel, (51% to 100% diamond)
DD TCI Full Diamond Diamond enhanced cutting structure (nose, middle and gauge inserts)
DD2 TCI Full Diamond Diamond enhanced cutting structure, (nose, middle and premium gauge inserts)
G TCI Cutting Structure Tungsten carbide cone shell protection (Super-D Gun)
Q All Hydraulics Q-Tube hydraulics
V All Hydraulics V-Flo hydraulics
E All Hydraulics Extended Nozzle Tubes
VE All Hydraulics Vectored Extended Nozzle Tubes
J3 All Hydraulics Dome Jets (3 jets in the bit dome)
C All Hydraulics Center jet
L All Leg Protection Lug pads with tungsten carbide inserts
LD All Leg Protection Lug pads with diamond inserts
R All Leg Protection Upper legback SRT carbide insert cluster and PS feature
RD All Leg Protection Upper legback SRT diamond insert cluster and PD feature
PS All Leg Protection SRT tungsten carbide leg protection
PD All Leg Protection SRT diamond leg protection
P All Leg Protection Modified PS feature pattern; Note: West Texas bits only
NOTE: Black text applies to MT and TCI. Blue text applies to MT only. Green text applies to TCI only
Turbodrilling
Smith Neyrfor Turbodrilling-The Faster Way to Better Drilling PerformanceTurbodrilling
A History of Technical Leadership
Smith Neyrfor introduced turbodrilling to the modern Western
oil industry more than half a century ago and, since that time,
the company has maintained its technical leadership position in
the design, manufacture and application of high performance
turbodrills for the oilfield. The modern era of advanced
directional drilling techniques actually began with turbodrills
when, in 1982, Neyrfor introduced the first steerable drilling
system, a steerable turbodrill using offset stabilizers to control
both hole direction and inclination. In 1992, Neyrfor continued
its role as directional innovator when the first turbodrill with an
adjustable bent housing was introduced.
Another Neyrfor “first” was the introduction of synthetic diamond bearings in a turbodrill, an
innovation that was instrumental in greatly extending the operating life and reliability of turbodrills
- particularly in deep, hot-hole applications. And throughout its history, Neyrfor has continued to
make advances in power section design to further increase power output, improve energy
efficiency and achieve higher reliability.
In August 2002, Neyrfor became part of Smith International, Inc. With the increasing importance of
matching the downhole power characteristics to the drill bit, Smith Neyrfor is now well positioned to
leverage the global capabilities of Smith to continue its tradition of innovation and the growth of
turbodrilling to an ever-expanding range of applications and formation types.
53
The Turbodrilling Advantage
Smith Neyrfor Turbodrills vs. PDMs
Both turbodrills and positive displacement motors convert hydraulic energy provided by the drilling
rig's mud pumps to mechanical energy in the form of rotation and torque directly at the drill bit.
Both can be configured for directional applications, where the tool must be steerable, or straight-
hole drilling where supplemental power to improve drilling efficiency is the primary objective.
Energy Efficiency: As an energy conversion device, turbodrills and PDMs provide more power to
the bit when they are more efficient. Because of the nature of the free-running, balanced design of
a turbodrill, it is far more efficient than a PDM, which creates more internal friction and wastes
energy due to its unbalanced, eccentric design.
Turbodrill Rotor/Stator Pair
Power Output: Superior energy efficiency of the
turbodrill translates directly into more power available
at the bit to destroy the rock faster for higher rates of
penetration. And, because the power output of a
turbodrill does not deteriorate over time, the turbodrill
maintains its uniformly high power output. As the
elastomer stator in a PDM wears, "leakage" through the
tool increases, and the power output of the PDM
degrades continuously throughout the run.
Reliability/Operating Life: Turbodrills, designed
as precision high performance dowhole tools, routinely
achieve downhole run times of over 400 hours and, in
some circumstances, even above 600 hours. Inherent
limitations in the basic PDM tool design generally limit
even the best PDMs to just over 200 hours.
Vibration: Direct evidence of the superior vibration
characteristics of the turbodrill is available any time a
turbodrill or PDM is surface-tested. The turbodrill
appears virtually motionless as it hangs in the derrick
being tested, while the PDM thrashes about violently as
the effects of the unbalanced power section design
become all-too apparent. Downhole dynamics
measurements routinely confirm this difference in
vibration, Excessive downhole vibrations have been
shown to damage expensive downhole electronics,
contribute to accelerated bit wear and adversely affect
the efficiency of the total drilling operation.
54
Relative Power Output: Turbodrill vs. PDM
Ou
tpu
t P
ow
er
Time Downhole
PDM
Turbodrill
Typical Operating Life
Ho
urs
Turbodrill PDM
500
400
300
200
100
0
TurbodrillingSmith Neyrfor Turbodrilling-The Faster Way to Better Drilling Performance
Vibration: Turbodrill vs. PDM
Vibration Levelwith PDM
Dep
th
High Vibration Low
Vibration Levelwith Turbodrill
14700
14800
14900
15000
HTHP Capability: Because a turbodrill has no elastomeric material in the power section, tool performance is
exceptional even when run at high temperatures and pressures. The use of elastomers in a PDM's power section
often results in rapid wear and down-hole tool failure
because the physical properties of rubber compounds
degrade at higher temperatures. PDMs can be designed
with reduced elastomers but cannot eliminate it
entirely; hence, the weakness remains.
Directional Capability: For any given bent sub angle, turbodrills have been shown to provide greater directional responsiveness and thus
can deliver a higher DLS when it is necessary to achieve directional objectives or can achieve normal
requirements with a lesser bend. Also, turbodrills operate with much less fluctuating and reactive torque than
PDMs making it much easier to control and predict the toolface and resultant directional response.
Underbalanced Drilling Capability: Turbodrills can
operate effectively in applications where two-phase drilling fluid
is used versus PDMs, which require a liquid mud to operate.
Borehole Quality: Turbodrills consistently deliver a smooth
and concentric wellbore. With the superior toolface control and
high degree of stabilization on the turbodrill, hole spiraling and
severe localized doglegs are minimized. The result is trouble-
free running of casing and a reduction in cementing costs
because of the superior quality of the wellbore.
Operating Cost: The ultimate advantage of a turbodrill is the
tool's ability to consistently deliver a lower cost-per-foot drilled
versus a PDM. Increasingly, the higher cost per hour of the more
robust, high performance turbodrill is far surpassed by the direct savings in drilling time and the substantial
reduction in tripping time due to higher tool reliability and longer bit life.
Smith's extensive capabilities in advanced materials technology, substantial drilling applications expertise,
ability to model the total drilling process and leadership position in drill bit design will ensure that Smith Neyrfor
will achieve a future of technical leadership for many years to come.
55
Turbodrilling
PDC Bearing Assembly
Smith Neyrfor Turbodrilling-The Faster Way to Better Drilling Performance
Smith Borehole Enlargement
Smith Borehole Enlargement combines leading technologies and products
®Rhino XS Reamer enlarges existing or pilot wellbores
Smith Services and Smith Technologies have combined their wellbore enlargement products and technical
capabilities into a new operating group, Smith Borehole Enlargement (SBE). SBE unites Smith Services' leading ® ®wellbore enlargement technologies, including Rhino Reamer and Reamaster , with Smith Technologies'
innovative drilling products and design simulation systems such as Quad-D™ bi-center bits and
IDEAS modeling technology.
SBE will ensure the delivery of high quality wellbores through its unique combination of
knowledge, experience and worldwide resources. Smith Borehole Enlargement offers a
breadth of tools and engineering know-how that will ensure a superior wellbore in any
application.
The hydraulically operated Rhino XS Reamer is an expandable, concentric reaming tool to
enlarge wellbore diameters up to 25% for improved casing running and cementing clearance.
The tool is effective in a variety of formations where simultaneous drilling and hole enlargement
reliability is critical. The enlargement operations can be run with directional drilling assemblies
in tight-tolerance casing designs, and the tool is compatible with all types of rotary steerable
systems.
The tool body houses three equally-spaced cutter blocks with PDC inserts to provide a durable
cutting structure for both drilling and backreaming. The cutter blocks feature integral stabilizer
pads that limit side cutting action to achieve good hole wall quality.
Rhino XS Reamer features a one-piece cutter block/extension mechanism for increased
durability. This one-piece body design increases torque and load carrying capacity, and the
balanced mass design eliminates detrimental vibrations while drilling.
An integrated cutter block lock-up system prevents cutter block actuation during shoe track
drill-out. The cutter blocks deploy simultaneously to produce a concentric, full gauge, high
quality wellbore. Pressure indicators at the surface signal full cutter block deployment while the
cutter blocks collapse when the pumps are off.
Field-changeable nozzles travel with the cutter blocks to ensure optimum cleaning at every
opening diameter. The tool's large bore accommodates high volume fluid requirements with
optimized fluid distribution between bit and cutter blocks. This high fluid capability also
accommodates the fluid requirements of rotary steerable systems and directional assemblies.
SBESmith Borehole Enlargement
57
®Rhino SS - Stabilization System (RSS)
When well profiles and modern drillstrings both become more complex, reducing drillstring vibration becomes an
important factor in building a quality wellbore. Vibration shortens the life of drill bits and reamers and reduces the
life of MWD, LWD and rotary steerable systems. In severe cases, drillstring vibration can even lead to the BHA
being lost in the hole, requiring significant investments of time and money to remediate.
As the industry leader, Smith Borehole Enlargement has developed the Rhino Stabilization System to reduce
drillstring vibration in demanding borehole enlargement operations. The RSS utilizes an abrasion-resistant
stabilizer block, deployed with the proven "Z Drive" system used on the Rhino XS reamer. When run above the
Rhino XS, the Rhino Stabilizer provides concentric, stable points of contact in the enlarged hole section, which
improves drilling efficiency and performance by significantly reducing drillstring vibration.
The Rhino Stabilization System is an integrated configuration consisting of the Rhino XS Reamer and the Rhino
Stabilizer.
! Concentric stabilizer increases lateral support in the enlarged wellbore.
! The introduction of the stabilizer improves dynamic stability.
! Stabilizer activation method is double ball drop, the same as the Rhino XS Reamer.
! Use of diamond enhanced inserts in the stabilizer blocks provides superior wear resistance.
! Configuration is typically run undergauge and 30 feet above the Rhino XS Reamer.
Rhino Stabilizer Block
Z-Drive Tongue& Groove Actuation
Tungsten CarbideHardfacing
Diamond EnhancedGauge Inserts
Stabilizer Blocks ProvideConcentric Stabilization
58
SBESmith Borehole Enlargement
IDEAS technology optimizes the performance of the entire drilling assembly
®Reamaster for underreaming in all drilling environments
The Integrated Dynamic Engineering Analysis System originated with Smith Bits as a design platform to improve
the bit design process. This model has now been expanded to allow the analysis of the entire drillstring and each of
its components. Reamers, stabilizers, hole openers, MWD/LWD and any
other component of the BHA can be modeled to predict its behavior in the
drillstring. The first application of this technology for SBE is designing the
new Rhino XS cutter blocks. Using the power of the IDEAS software, these
cutting structure designs can now be tailored to specific applications and will
provide the customer with significant increases in reamer performance.
Operators can be confident obtaining superior performance from the
customized reamer cutting structures and know that the reamer will be
optimized for performance with the rest of the BHA components, as well as
the drill bit.
The Reamaster underreamer is used to enlarge the wellbore size below a restriction, when
drilling wells with minimum clearance and expandable casing programs. The tool is also
applicable in wells where gravel packs are to be installed as well as expandable sand screen
completions.
The tool reduces an operator's drilling costs since it is designed to underream long intervals at
increased penetration rates. It permits a slimmer top-hole for a given diameter production
zone, or a larger-than-standard production zone for a given hole size. Since the activation of
the tool is controlled from surface, the Reamaster's capability of drilling-while-underreaming
allows the operator to underream without tripping out of the hole. The result is improved
drilling economics when selective sections of the wellbore require enlargement.
Reamaster is designed with two large, forged one-piece cutter arms with an integral journal to
retain the cutters and results in an increased cross sectional area at the underreamer cutter
pockets. This change in the fundamental design allows the tools to carry up to 60,000 lbs of
drilling weight, enabling the tool to spend more time on bottom, handle bigger shocks and more
torque, and significantly increase penetration rates compared with competitors’
underreamers. This design also provides more room for larger sealed bearing and PDC cutters
for optimized underreaming performance.
Smith Bits designed and developed cone-type cutters specifically for underreaming that
includes sealed bearings for extended bit life. The cutters produce a true rolling motion that
significantly increases performance and cutter life. Additionally, the cutting structure is
designed to match different formations, and can be provided with milled teeth, TCI or PDC
cutting structures.
59
SBESmith Borehole Enlargement
Hole Openers & Underreamers
An unmatched array of tools equips SBE to handle any borehole enlargement application. In addition to the Rhino
reamer, Reamaster and the Quad D bi-center bits, Smith Borehole Enlargement offers the broadest underreamer
and hole opener product line in the industry. These products include the Drilling Type Underreamer, the Rock Type
Underreamer, and the SHO, GTA, STA Hole Openers. With cutting structures that run the gamut from PDC to steel
milled tooth to tungsten carbide inserts, there is an SBE hole opener that will get the job done in any application.
SBE truly is superior borehole expertise.
60
Fixed Diameter HoleOpeners with O.D. less than
26” have 3 cutters
Fixed Diameter HoleOpeners with O.D. 26” or
larger have 4 cutters
DTU w/BullnoseRock-Type Underreamer
SBESmith Borehole Enlargement
QUAD-D, Dual Diameter Drift and Drill bits provide hole opening through installed casing or liner sections. This
family of aggressive matrix and steel body bits is designed to provide durability, reduce torque response, maintain
tangents, and reduce sliding time without compromising efficiency when drilling either float equipment or
formation. It features a strong, one piece construction and a very low overall height that enhances directional
capabilities when drilling with downhole motors.
QUAD-D Nomenclature
16-1/2” x 20”QDS7313PX
! Drill-Out Capability! Directional Responsiveness! Diameter Control! Design-Specific
14-3/4” HoleMaintained
12-1/4” x 14-3/4”QDS7213
Pilotgaugesection
QUAD-D bits were originally designed and developed by
Smith Bits and they are now available through SBE,
Smith’s focused provider of a full range of borehole
enlargement solutions.
Vibration is controlled by force and mass balancing,
employment of spiral blades and gauge, asymmetrical ™ blade layout, and use of Lo-Vibe inserts. Because of
the resulting bit vibration control, bit rotation is
maintained about the true bit axis ensuring accurate
finished hole diameter and quality. Hydraulic ports are
located to provide efficient cuttings removal and
cleaning of both the pilot and reaming sections. A
unique gauge profile prevents cutters from contacting
and damaging the casing; it also provides a high degree
of stabilization and gauge protection. QUAD-D has
proven drift and drill success in a broad range of
applications. Excellent performance is achieved in both
vertical and directional applications in a variety of
formations, from soft to hard, and non-abrasive to
abrasive.
M/S - Matrix or Steel
QUAD-D Technology
Q D S 7 3
™QUAD-DDual Diameter Drift & Drill
Type Size Availability
3-3/4” X 4-1/8”QDM3209QDM3309QDM4209QDM4213QDM7309QDM7313QDMS4209QDS3209QDS4209QDS5209QDS5213
QDS5216QDS5219QDS6309QDS7213QDS7309QDS7313
1 3
Pilot Blade Count
Reamer Blades to Full Diameter
Cutter Size
5-7/8” X 6-1/2”
3-3/4” X 4-1/8”
6” X 7”
6” X 7”
8-1/2” X 9-7/8”, 10-5/8” X 12-1/4”
3-3/4” X 4-1/8”
4-3/4” X 5-5/8”, 4-1/2” X 5-3/4”
4-3/4” X 5-5/8”, 6”X 7”
8-1/2” X 9-7/8”, 12-1/4” X 14-3/4”,14-1/2” X 17-1/2”
6-1/2” X 7-1/2”, 8-1/2” X 9-7/8”
12-1/4” X 14-1/4”
7-1/2” X 8-1/2”, 8-1/2” X 9-7/8”, 9-1/2” X 11”, 10-5/8” X 12-1/4”, 16-1/2” X 20”
7” X 8-3/8”
8-1/2” X 9-7/8”, 14-1/2” X 17-1/2”
17” X 20”
6” X 7”
61
The versatility of QUAD-D products is best demonstrated by the range of applications that they drill. The GeoReam
is well suited to be run directly above the pilot bit for directional applications. It is the recommended alternative to
the QUAD-D bit in applications in which a PDC cutting structure is not the best option for the pilot bit. Although
compact in length, the stability-enhancing technology used in the GeoReam ensures optimal hole quality while
drilling. With longer pilot conditioning sections and drill string connections, QUAD-D Reamers are designed to
maximize performance in rotary applications. The longer pilot conditioning section acts like a string stabilizer to
ensure centralization and stabilization. This tool is intended to be run with various BHA configurations, including
rotary steerable systems.
10-5/8” x 12-1/4”QDR5313
! Directional & BHA Flexibility! Drill-Out Capability! Diameter Control! Design Specific
8-1/2” x 9-7/8”QDG5216
8-1/2” x 9-7/8”QDR5313
The QDR has drill collar connections for string placement
Fishing Neck
Tong Neck
6” x 7” QDG5316
™QUAD-DTMDual Diameter Drift & Drill - Reamer & GeoReam Products
QUAD-D Nomenclature
G / R - GeoReam or Reamer Product
QUAD-D Technology
Q D G 5 3 1 6
Pilot Blade Count
Reamer Blades to Full Diameter
Cutter Size
Type Size Availability
QDG5216
QDG5313QDG5316QDG7313QDR5213QDR5313
QDR5319QDR6313QDRS5216QDRS6313
8-1/2” X 9-7/8”, 14-1/2” X 17-1/2”, 16” X 20”, 17” X 20”, 18-1/8” X 22”
5-5/8” X 7-1/8”
16-1/2” X 20”
6-5/8” X 7-1/8”
7-1/2” X 8-1/2”, 10-5/8” X 12-1/4”
6” X 7”
13-7/8” X 17”
8-1/2” X 9-7/8”, 9-1/2” X 10-3/4”, 10-5/8” X 12-1/4”, 12-1/4” X 14-3/4”14-1/2” X 17-1/2”
12-1/4” X 14-1/2”
16-1/2” X 19”
62
Type Size Availability
SHO516
SHO519
SHO716SHOS516
8-1/2” X 10-5/8”
9-1/2” X 10-5/8”
17-1/2” X 24”
8-1/2” X 12-1/4”8-1/2” X 17-1/2”
12-1/4” X 14-3/4”
12-1/4” X 17-1/2”
12-1/4” X 17”
SHOStaged Hole Openers
8-1/2” x 12-1/4”SHO519
(shown inverted)
Staged Hole Openers Nomenclature
SHO - Staged Hole Opener
S 1 9 Cutter Size
5
Blade Count
H O
Concentric Staged Hole Openers (SHO) from Smith Bits have been developed from a tradition of application
knowledge and technical excellence gained from the success of QUAD-D reaming products.
SHO tools incorporate precision-engineered cutting structures to ensure fast, smoothly drilled and high quality
hole opening under a wide range of application conditions. SHO tools are run successfully on rotary and rotary
steerable assemblies in both straight and deviated holes.
While the overall SHO cutting structure is balanced, it is divided into sections, each
serving a specific purpose.
Stage One - Pilot Bit! Using either a fixed cutter or roller cone bit, the pilot drills the initial hole
diameter. A bull nose can also be used to follow a pre-drilled pilot hole.! SHO assemblies can be used with multiple pilot configurations for specific
applications.! SHO can be placed in either a near-bit position or within the BHA for various
drill string configurations.
Stage Two - SHO Pilot Section! The pilot section consists of one or two rows of cutting structure to recondition
the pilot hole and remove any swelling clays or moving halites.! Gauge pads provide initial stabilization as the SHO begins the staged reaming
process to reduce stick-slip, whirling or off-center tendencies.
Stage Three - SHO Pilot Conditioning Section (PCS)! Cutting structure is designed to minimize work rates on each cutter position for
maximum durability. By stress relieving the formation with this intermediate stage, larger hole drilling can be done at a more aggressive penetration rate.
! The third stage re-centralizes the SHO on the given well trajectory in both vertical and directional applications.
! Gauge pads and gauge trimmers provide the main stabilization for the SHO.! Gauge pad lengths in the section may vary depending on whether the
application calls for a near bit or drill string placement.
Stage Four - SHO Reaming Section! This cutting structure completes the final hole diameter. With the formation
already stress-relieved, the reaming section remains aggressive even in more competent formations.
! Gauge trimmers and spiraled gauge pads ensure good hole quality.! Gauge pads in this section are kept short in length for directional needs.
8-1/2” X 13-1/2”
12-1/4” X 17-1/2”
12-1/4” X 16”
17-1/2” X 24”
63
Percussion Hammers& Bits
0 20 40 60 80ft/lb
*ENHANCED INSERT
Percussion Hammers
®IMPAXImpax hammer is designed for oilfield conditions
Smith's Impax hammer features a patented hardened steel guide sleeve design that replaces and eliminates the
blow tube found in conventional hammers. This enhanced design significantly improves reliability and optimizes
energy transfer between the piston and the bit. Blow tubes are typically the component most likely to fail in
conventional hammers. Eliminating the plastic blow tube also increases reliability by eliminating failures due to
high temperature, erosion caused by misting, shock and vibration, and abrasive wear.
The Impax hammer's large lower chamber increases performance in the high back-pressure conditions created by
deep-hole drilling, high circulation volumes and misting and influx. The combination of the hardened steel guide
sleeve and the larger chamber provide the Impax hammer with the ability to handle more water from mist and/or
influx than conventional hammers. The Impax hammer handles 10%-20% more water volume than conventional
hammers, saving the operator a trip when the water incursion would cause a conventional hammer to be tripped
out of the well.
Smith’s Impax hammers and Impax drill bits are a winning combination for superior reliability, durability and
performance.
65
IMPAX 8 Percussion Hammer
SMITH PERCUSSION
66
Impax bits provide fast ROP and exceptional durability
Impax bits feature industry's most reliable retention
system
The Impax line of premium percussion bits offers the customer an
exceptional combination of reliability, durability and performance.
Impax bits feature 100% tough and durable diamond enhanced
inserts that increase footage drilled and lower cost per foot. The PD
gauge feature eliminates the need for reaming, improving the life of
the subsequent bit and providing a quality wellbore for running
casing. Three exhaust ports optimize bit-face cleaning for longer life
and better penetration rates, and the bit's concave center optimizes
directional control.
When encountering hard rock formations that require the use of a
percussion hammer, Smith Bits' Impax line of bits offers the
industry's most reliable retention system. The patented retaining
system prevents the loss of the bit head in the hole, saving the
operator the cost of expensive fishing operations associated with
recovering material from the wellbore. Reducing the risk of losing
the bit also reduces the risk of having to drill a sidetrack.
Impax & DIGR Percussion Bits
®IMPAX
DIGR™ Bits (Diamond In Gauge Row)
The DIGR (Diamond In Gauge Row) line of hammer bits is the cost-
effective choice for drilling applications that do not require cutting
structures with 100% diamond enhanced inserts.
These bits offer a full range of cutting structure layout options, but
use diamond enhanced inserts (DEI) only in the gauge row. DIGR
bits provide excellent ROP and durability in less demanding
formations that do not require the cutting structure to have 100%
DEI in order to meet performance objectives.
DIGR bits also utilize the same industry leading retention system as
the IMPAX products.
SMITH PERCUSSION
Hammer Bit Nomenclature
®IMPAX
Hammer Bit Nomenclature
Type
H0806
H1006
H1006
H1006
H1006
H1209
H1209
H1209
H1206
H1209
H1209
H1512
H1509
H1509
H1509
H1509
H1509
H1209
H1209
H1209
H1812
H1809
Current FeaturesCDFGMN
PDRTVX67
Carbide InsertDiamond Enhanced Insert (DEI)FlatDiamond on GaugeModifiedNon-RetainableOptional Gauge ProtectionRetainableRetainable “V” ThreadConcaveConvexØ 6/8” (18mm) DEI (insert diameter)Ø 7/8” (22mm) DEI (insert diameter)
Available FeaturesFor Bit
X,6,R,D,PD
X,6,R,D,G
X,6,R,D,G
X,6,R,D,G
X,6,R,D,G
V,7,R,D,PD
V,7,R,D,PD
V,7,R,D,PD
V,7,R,D,PD
V,7,R,D,PD
V,7,R,D,G,PD
V,6,R,D,G,PD
V,7,R,D,PD
V,7,R,C,D,PD
V,7,R,C,D,PD
V,7,R,C,D,PD
V,7,R,D,PD
V,7,R,D,PD
V,7,R,D,G,PD
V,7,R,D,G,PD
V,7,R,D,G,PD
V,7,R,D,G,PD
As a leader in the oil field percussion industry, we are striving to create a nomenclature system that will allow our customers to easily understand the characteristics of a particular bit. The nomenclature allows our customers to readily identify the cutting structure, features, and spline configuration of our bits.
The nomenclature is structured as follows:
Size In eighths (3 digits)
Prefix H denotes hammer bit (1 digit)
Descriptor - Number of gauge inserts (2 digits) - Number of adjacent to gauge inserts (2 digits)
Suffix Cutting structure material and/or configuration of cutting structure layout (1 digit)
Features found on a specific size and type bit (Varies)
A table showing our current product offering is provided for ease of reference.
061
062
063
064
066
077
083
084
086
086
087
087
094
095
096
097
105
110
122
123
146
174
Size(eighths)
67
SMITH PERCUSSION
Example: 086 H1512D
086
Size
H 15 12 G
Prefix H = Hammer Bit
Descriptor = Number of Gauge Inserts
Descriptor = Number of Adjacent to Gauge Inserts
Suffix = iamond, Diamond on auge or arbide
D GC
Typical spline design
D
C
New Spline Nomenclature
New Spline Name Old Spline Name
Ingersoll Rand
R04
R06
R08
R12
Q06
Q08
Q12
Q20
T09
IR340
IR360
IR380
IR112
QL60
QL80
QL120
QL200
TD90
Numa
N10
N12
N18
N100
N125
N180
Mission
M10
M12
M15
M18
SD10
SD12
SD15
SD18
Epley
E12 E12000
Halco
H06 H6
Example:086 H1512D
Optional gaugeprotection
Rope threads for secondary retention
Gauge Insert
Face air holes Adjacent Gauge Insert
Typical concaveface design
Hammer Bit Nomenclature
®IMPAX
68
SMITH PERCUSSION
Available Hammer Bit Features & Options
®IMPAX
69
Face Inserts:
Gauge Inserts:
Bit Profile Shapes:
C Feature - Carbide Insert
D Feature -Diamond Enhanced Insert (DEI)
6 Feature -ø6/8” (18mm) DEI
7 Feature -ø7/8” (22mm) DEI
G Feature - Diamond (DEI) in Gauge Row
F Feature - Flat
M Feature - Modified
Feature: All carbide cutting structure
Advantage: Excellent durability and abrasion resistance
Benefit: Excellent drilling performance in soft to medium-soft formations, at a cost effective price
Feature: All DEI cutting structure
Advantage: Exceptional durability and abrasion resistance
Benefit: Exceptional drilling performance in longer, hard formation intervals
Feature: Ø 6/8” DEI gauge cutting structure
Advantage: Allows for utilization of heavy-set diamond gauge cutting structures
Benefit: Eliminates the need for reaming, improving life of the subsequent bit, and providing a quality hole for running casing
Feature: Ø 7/8” DEI gauge cutting structure
Advantage: Allows for utilization of diamond gauge cutting structures with improved impact damage resistance
Benefit: Eliminates the need for reaming, improving life of the subsequent bit, and providing a quality hole for running casing
Feature: A cutting structure utilizing carbide face inserts and DEI gauge inserts
Advantage: Exceptional gauge durability and abrasion resistance
Benefit: Exceptional bit gauge life when drilling long, medium-soft formation intervals
Feature: Flat-bottom with a single gauge angle bit head profile
Advantage: Allows for utilization of heavier set cutting structures on the bit face
Benefit: Exceptional drilling performance in hard formation intervals
Feature: Non-standard bit head profile
Advantage: Unique geometry incorporated for specific operating parameters
Benefit: Enhanced performance for special drilling applications
Bit Profile Shapes Cont’d:
Bit Head Retention:
Gauge Reinforcement:
V Feature - Concave
X Feature - Convex
N Feature - Non - Retainable
R Feature – Retainable
T Feature - Retainable “V” Thread
PD Feature - Optional Gauge Protection
Feature: Concave bottom with a dual gauge angle bit head profile
Advantage: Provides additional drilling stability and directional control
Benefit:
Feature:
Advantage:
Benefit:
Exceptional drilling performance in medium-soft to medium formation intervals where hole deviation is a primary concern
Flat-bottom with a dual gauge angle bit head profile
Allows for utilization of heavy-set face and gauge cutting structures
Exceptional drilling performance in medium to medium-hard formation intervals
Feature: No retaining feature on the bit head (standard fishing threads)
Advantage: Allows the bit to be compatible with non-Smith hammers where bit retention isn’t applicable
Benefit: Flexibility to use the bit in various BHA assemblies such as water wells, construction, etc.
Feature: Smith-patented bit head retention system (U.S. Patent 5,065,827)
Advantage: Prevents the loss of the bit head in the hole
Benefit: Saves the cost of sidetracking or fishing
Feature: Slightly modified Smith patented bit head
Advantage: Allows bits with larger diameter shanks to be run with a retention system (U.S. Patent 5,065,827)
Benefit: Saves the cost of sidetracking or fishing
Feature: All diamond gauge reinforcement
Advantage: Exceptionally extends the life of the bit gauge
Benefit: Eliminates the need for reaming, practice of reducing hole size after pulling a non-PD hammer bit, and improving life of the subsequent bit provides a quality hole for running casing
SMITH PERCUSSION
Reference Tools
2Total Flow Area (TFA) of Standard Nozzles (in. )
NozzleSize (in)
Number of Nozzles
1 2 9876543 10
TOTAL FLOW AREA CHART
REFERENCE
0.038
0.049
0.062
0.077
0.093
0.110
0.130
0.150
0.173
0.196
0.249
0.307
0.371
0.442
0.075
0.098
0.124
0.153
0.186
0.221
0.259
0.301
0.345
0.393
0.497
0.614
0.742
0.884
0.113
0.147
0.186
0.230
0.278
0.331
0.389
0.451
0.518
0.589
0.746
0.920
1.114
1.325
0.150
0.196
0.249
0.307
0.371
0.442
0.518
0.601
0.690
0.785
0.994
1.227
1.485
1.767
0.188
0.245
0.311
0.383
0.464
0.552
0.648
0.752
0.863
0.982
1.243
1.534
1.856
2.209
0.225
0.295
0.373
0.460
0.557
0.663
0.778
0.902
1.035
1.178
1.491
1.841
2.227
2.651
0.263
0.334
0.435
0.537
0.650
0.773
0.907
1.052
1.208
1.374
1.740
2.148
2.599
3.093
0.301
0.393
0.497
0.614
0.742
0.884
1.037
1.203
1.381
1.571
1.988
2.454
2.970
3.534
0.338
0.442
0.559
0.690
0.835
0.994
1.167
1.353
1.553
1.767
2.237
2.761
3.341
3.976
0.376
0.491
0.621
0.767
0.928
1.104
1.296
1.503
1.726
1.963
2.485
3.068
3.712
4.418
71
7/32
8/32
9/32
10/32
11/32
12/32
13/32
14/32
15/32
16/32
18/32
20/32
22/32
24/32
1 141312111098765432
1 1 ¼ 1 ½ 1 ¾ 2 2 ¼ 2 ½ 132 /16 3 3 ¼ 3 ½ 3 ¾ 4
DRILL COLLAR SPECIFICATIONS
REFERENCE
72
Drill Collar Weight (Steel) (lbs per foot)
Drill Collar ID, inches
2-7/8”
3”
3-1/8”
3-1/4”
3-1/2”
3-3/4”
4”
4-1/8”
4-1/4”
4-1/2”
4-3/4”
5”
5-1/4”
5-1/2”
5-3/4”
6”
6-1/4”
6-1/2”
6-3/4”
7”
7-1/4”
7-1/2”
7-3/4”
8”
8-1/4”
8-1/2”
9”
9-1/2”
9-3/4”
10”
11”
12”
19
21
22
26
30
35
40
43
46
51
18
20
22
24
29
33
39
41
44
50
16
18
20
22
27
32
37
39
42
48
54
61
68
75
82
90
98
107
116
125
134
144
154
165
176
187
210
234
248
261
317
379
35
37
40
46
52
59
65
73
80
88
96
105
114
123
132
142
152
163
174
185
208
232
245
259
315
377
32
35
38
43
50
56
63
70
78
85
94
102
111
120
130
139
150
160
171
182
206
230
243
257
313
374
29
32
35
41
47
53
60
67
75
83
91
99
108
117
127
137
147
157
168
179
203
227
240
254
310
371
44
50
57
64
72
79
88
96
105
114
124
133
144
154
165
176
200
224
237
251
307
368
60
67
75
83
91
100
110
119
129
139
150
160
172
195
220
232
246
302
364
64
72
80
89
98
107
116
126
136
147
158
169
192
216
229
243
299
361
60
68
76
85
93
103
112
122
132
143
154
165
188
212
225
239
295
357
72
80
89
98
108
117
128
138
149
160
184
209
221
235
291
352
93
103
113
123
133
144
155
179
206
216
230
286
347
84
93
102
112
122
133
150
174
198
211
225
281
342
Cost per Foot (CPF)
CPF =Bit Cost + Rig Cost (Trip Time + Drilling Time)
Footage Drilled
Pressure Drop ( ∆P)2
Flow Rate x Mud Weight2
10,856 x TFA∆P =
Hydraulic Horsepower (Hhp)
(Bit Pressure Drop) (Flow Rate)
1,714Hhp =
Hole Area (A )h
2 x Hole Diameterπ
4A = h
Hydraulic HP per Square Inch (HSI)
Hydraulic Horsepower
Hole Area (Sq. In.)HSI =
Drilling Formulas
Standard Measurement UnitsTo ObtainQuantity/Property Units Multiply By Symbol
MEASUREMENT UNITS AND DRILLING FORMULAS
REFERENCE
73
DepthWeight-on-Bit
Nozzle SizeDrill RateVolume
Pump Output & Flow Rate
Annular Velocity &Slip VelocityLinear Length &DiameterPressure
Mud DensityMud GradientFunnel ViscosityApparent & PlasticViscosity Yield PointGel Strength &StressCake ThicknessFilter LossTorque
ft.lbs.
32nds in.ft./hr.barrelsU.S. gal./strokeU.S. gal./min.bbls./stroke
bbls./min.ft./min.
in.
psi
lbs./gal. (U.S.)psi/ft.secs./qt. (U.S.)centipoise
2lb.f/100ft.
32nds in.mm or ccft./lbs.
0.30480.445
-44.535 x 100.7940.30480.1590
-33.785 x 10-33.875 x 10
an oil barrel is 30.159873 x m exactly
0.15900.3048
25.4
6.8950.0068950.06895119.8322.6211.0571
0.4788(0.5 for field use)0.79411.3358
metersdecanewtontonnemillimetersmeters/hourcubic meterscubic meters/strokecubic meters/minutecubic meters/stroke
cubic meters/minutemeters/minute
millimeters
kilopascalsmegapascalsbarkilograms/cubic meterkilopascals/meterseconds/litersmillipascal seconds
pascals
millimeterscubic centimetersnewton meters
mdaNtonnemmm/hr.
3m3m /stroke3m /min.3m /stroke
3m /min.m/min.
mm
kPaMPabar
3kg/mkPa/ms/lmPas
Pa
mm3cm
Nm
Buoyancy Factor
Mud Density
1.001.021.041.061.081.101.121.141.161.181.201.221.241.261.281.301.321.341.361.381.401.421.441.461.481.501.521.541.561.581.60
Mud DensityFactork
Factork(kg/l) (lb/gal) 3(lb/ft ) (kg/l) (lb/gal) 3(lb/ft )
8.358.518.688.859.019.189.319.519.689.85
10.0110.1810.3510.5210.6810.8511.0211.1811.3511.5211.6811.8512.0212.1812.3512.5212.6812.8513.0213.1813.35
62.463.764.966.267.468.769.971.272.473.774.976.277.478.779.981.282.483.784.986.287.488.789.991.292.493.794.996.297.498.799.9
0.8730.8690.8670.8640.8620.8590.8570.8540.8520.8490.8470.8440.8420.8390.8370.8340.8320.8290.8270.8240.8220.8190.8170.8140.8120.8090.8370.8040.8010.7980.796
1.621.641.661.681.701.721.741.761.781.801.821.841.861.881.901.921.941.961.982.002.022.042.062.082.102.122.142.162.182.202.22
13.5213.6813.8514.0214.1814.3514.5214.6814.8515.0215.1815.3515.5315.6915.8616.0216.1816.3616.5316.6916.8617.0217.1817.3617.5317.6917.8618.0218.1918.3618.54
101.2102.4103.7104.9106.2107.4108.7109.9111.2112.4113.7114.9116.2117.4118.7119.9121.2122.4123.7124.9126.2127.4128.7129.9131.2132.4133.7134.9136.2137.4138.7
0.7930.7910.7890.7860.7830.7810.7790.7760.7730.7710.7680.7650.7630.7600.7580.7550.7520.7490.7470.7450.7420.7390.7370.7340.7320.7290.7270.7250.7220.7190.717
Mud DensitySteel Density
hence: Buoyancy Factor (k) = 1
Apparent weight = Real Weight x Buoyancy Factor
BUOYANCY FACTOR
REFERENCE
74
!
! Grease the O-ring and replace it in the O-ring groove.
! Do not grease nozzles in Matrix bits before installation.
! Lightly grease nozzles in Steel bits and screw into jet ports.
! Hand tighten the nozzle with a tee wrench until snug. Damage may occur if a cheater bar is used on the tee wrench handle.
Remove the plastic plug and the O-ring from each nozzle port.
O-Ring SeriesSeries 30: 60007985Series 40: 60007985Series 50: 60019245Series 60 / Vortexx 60: 60003276
WrenchesSeries 30: 60007986Series 40: 60018251Series 50: 60024519Series 60: 60003448Vortexx 60: 60005675
Correct Nozzle Installation Helps Prevent Washouts
FIXED CUTTER BIT NOZZLE INSTALLATION
REFERENCE
Range (32nds)7 - 137 - 137 - 167 - 22
Range (32nds)8 - 128 - 16
Vortexx 60
N60 Series
N40 Series
N30 Series
N50 Series
Jet NozzlesSeries 30Series 40Series 50Series 60
PortsSteel BitsMatrix Bits
75
6-5/8” API PIN RESTRICTOR NOZZLE
REFERENCE
The pin restrictor nozzle is used in special applications for mud motors that require high bit pressure drops (650 - 850
psi) during operation. Pin restrictors are designed to split the total bit pressure drop between a nozzle in the pin and the
bit jet nozzles. Installing a pin restrictor allows larger nozzles to be installed in the bit face reducing the jet nozzle
velocity and bit body erosion.
Pin restrictors are installed in the pin of the bit and require a modified pin for installation. The modification can be made
on the bit when first built, or it can be retrofitted after the bit is manufactured. Two sleeves are designed to fit into the
modified pin. A nozzle sleeve can be installed when a pin restrictor is required as shown in Figure 8. A blank sleeve can
be installed when no pin restrictor is required as shown in Figure 9.
Pin restrictors do not run as efficiently as standard jet nozzles. An Excel spreadsheet has been developed to aid in the
selection of the pin restrictor and outer nozzle sizes. Contact your Smith Bits representative for the spreadsheet prior
to running a pin restrictor nozzle in a bit.
6-5/8” API Pin restrictor assembly with nozzles
76
Figure 8 Figure 9
Recommended Make-Up Torque Diamond & Fixed Cutter Drill Bits With Pin Connections
API Reg. Connection Size(inches)
RECOMMENDED FIXED CUTTER BIT MAKE-UP TORQUE
Bit Sub OD(inches)
Minimum(ft-lbs)
Normal(ft-lbs)
Maximum(ft-lbs)
REFERENCE
Notes:
1. Higher make-up torque values within the above ranges are recommended when high WOB is used.
2. Box connection bits should use make-up torque values between Minimum and Normal.
3. All connections must be lubricated with a joint compound meeting API requirements.
77
2-3/8
3
3-1/8
3-1/4
3-1/2
3-3/4 & Larger2-7/8
3-1/2
4-1/8
4-1/4
4-1/2 & Larger
5-1/2
5-3/4
6 & Larger
4-1/2
7-1/2
7-3/4 & Larger6-5/8
8-1/2
8-3/4
9 & Larger
7-5/8
10
10-1/4 & Larger8-5/8
1,970
2,660
3,400
3,380
5,080
5,700
6,940
8,400
13,700
18,100
18,550
40,670
41,050
53,100
63,500
68,600
96,170
107,580
2,280
3,100
3,950
3,950
5,900
6,600
8,050
9,850
16,000
21,100
21,600
47,300
47,800
61,850
73,750
79,800
102,600
114,700
2,450
3,300
4,200
4,200
6,300
7,000
8,550
10,500
17,000
22,400
22,900
50,200
50,750
65,670
78,300
84,750
108,950
121,800
The following general guidelines should be used to avoid bit damage before placing a bit into service and to ensure optimum performance.
FIXED CUTTER BIT FIELD OPERATING PROCEDURES
REFERENCE
!
cutters or inserts and gauge wear.! Make clean-up trip if necessary.! If drilling out float equipment with a PDC bit,
confirm that the product is PDC-drillable.
Inspect previous bit for junk damage, lost
!
on while inspecting.! Inspect the cutting elements for damage.! Verify inside of bit is clean and free of any
foreign matter.! Verify that bit gauge complies with API
standards.! Ensure that nozzle o-rings are in place.! Install proper nozzles; Do not over-tighten.
Use a rubber mat or wooden pad to set the bit
!
! Do not set the bit directly on the steel deck. Use a wooden pad or rubber mat.
! Fit the breaker to the bit.! Clean and grease the bit pin.! Lower the drill string onto the pin and engage
the threads.! Locate the bit and breaker in the rotary, and
make-up to the recommended torque.
Handle the bit with care.
!
through the rotary table.! Trip slowly through BOPs, casing shoes and liner
hangers.! Note the presence and location of tight spots
previously observed when pulling the previous bit out of the hole.
! Trip slowly through tight spots, dog legs or ledges.
! Wash the last three joints to bottom with full flow at 40 to 60 rpm.
! Approach the bottom cautiously by observing weight and rotary-torque indicators.
! Tag bottom gently and pick up off bottom approximately one foot.
! Circulate for 5 to 10 minutes with full flow at 40 to 60 rpm.
Remove the breaker and carefully lower the bit
Hole Preparation
Bit Preparation
Making Up the Bit
Tripping in the Hole
!
not recommended.! If reaming is necessary, observe the following
guidelines:! Ream with full flow! Use 40 to 60 rpm and 2,000 to 4,000 lbs.
weight-on-bit.! Ream slowly and avoid high torque.
Reaming long sections of under gauge hole is
Reaming
!
! Use 2,000 to 4,000 lbs. weight-on-bit and 60 to 80 rpm to establish bottom-hole pattern.
! Record pump strokes and stand pipe pressure.! Slowly break the bit in, drilling at least three
feet.! Increase the weight by 2,000-pound increments
to determine optimum drilling weight-on-bit.! While maintaining constant weight-on-bit, vary
the rotary speed to determine optimum drilling parameters.
Lower bit to bottom with full flow.
Bit Break-in
!
stringers to increase bit life.! Adjust rotary speed and weight-on-bit as
formation changes or stringers are encountered to maintain optimum drilling performance.
! After making connections observe the following guidelines:! Reset pump strokes and check standpipe
pressure.! Set bit approximately six inches off bottom
and pump for 30 seconds before drilling.! Slowly lower bit to bottom at 60 to 80 rpm.! Add weight slowly to attain previous weight-
on-bit, then increase rotary speed to previous rpm.
! Do not jam the bit back to bottom after making connections.
Reduce rotary speed in abrasive or hard
Drilling Ahead
78
MAXIMUM CONE DIMENSIONS - For Three-Cone Rock Bits
3 5 89 - 98 2 / 60 1 / 418 83 7 14 / 121 2 / 73 2 / 544 8 87 1 1 15 / - 6 / 149 - 159 4 / 108 3 / 798 4 4 81 3 1 16 / - 6 / 165 - 172 4 / 114 3 / 892 4 2 23 17 / - 8 187 - 203 5 / 133 4 1028 41 1 7 18 / - 8 / 206 - 216 5 / 149 4 / 1058 2 8 85 1 58 / - 9 219 - 229 6 / 156 4 / 1178 8 81 1 1 39 / - 9 / 232 - 241 6 / 165 4 / 1118 2 2 85 7 3 39 / - 9 / 245 - 251 6 / 171 4 / 1218 8 4 4
5 1 110 - 10 / 254 - 270 7 / 184 5 / 1408 4 27 7 711 - 11 / 279 - 302 7 / 200 5 / 1498 8 81 112 - 12 / 305 - 311 8 203 6 / 1564 8
1 5 513 / - 15 337 - 381 9 / 244 7 / 1944 8 81 116 406 10 / 260 8 / 2064 8
1 1 517 / 445 11 / 292 8 / 2192 2 8118 / 470 12 305 9 2292
1 520 508 12 / 318 9 / 2442 83 122 559 13 / 349 10 / 2674 21 124 610 15 / 387 11 / 2864 4
326 660 16 406 12 / 3244
28 711 17 432 13 330
Maximum MaximumSize Range Diameter Length
in. mm in. mm in. mm
Milled Tooth TCI Approx. Weight Approx. Weight
lbs. kg lbs. kg
10 5 12 5
15 7 20 9
35 16 45 20
45 20 55 25
75 34 85 39
90 41 95 43
95 43 100 45
125 57 130 59
135 61 145 66
165 75 175 80
195 89 210 95
205 93 225 102
345 157 380 173
410 186 450 205
515 234 545 248
525 239 570 259
625 284 700 318
1,000 455 1,170 532
1,385 629 1,400 636
1,450 659 1,550 704
1,550 704 1,650 750
APPROXIMATE BIT WEIGHTS
1 7 3 / - 3 / 2 8
REFERENCE
RECOMMENDED ROLLER CONE BIT MAKE-UP TORQUE
Size Range API Pin Size Recommended Torque
in. mm in. mm ft.-lbs. N-m
1 1 3 3 / - 4 / 89 - 114 2 / Reg. 60 3,000 - 3,500 4,000 - 4,8002 2 8
5 7 4 / - 5 118 - 127 2 / Reg. 73 6,000 - 7,000 8,000 - 9,5008 8
1 3 1 5 / - 7 / 137 - 187 3 / Reg. 89 7,000 - 9,000 9,500 - 12,0008 8 2
1 1 7 / - 9 194 - 229 4 / Reg. 114 12,000 - 16,000 16,000 - 22,0002 2
1 5 9 / - 28* 241 - 711* 6 / Reg. 168 28,000 - 32,000 38,000 - 43,0002 8
3 5 5 14 / - 28* 375 - 711* 6 / Reg. or 7 / Reg. 168 or 194 34,000 - 40,000 46,000 - 54,0004 8 8
1 5 5 18 / - 28* 470 - 711* 7 / Reg. or 8 / Reg. 194 or 219 40,000 - 60,000 54,000 - 81,0002 8 8
*Makeup torque must correspond to API pin connection for each bit size. Note: Some of the above bit sizes are available on special order with alternate pin connections.
79
NOZZLE COMPARISON CHART
REFERENCE
80
Jet Boss Series
Standard
Diverging
Mini
Extended Nozzles
55
55 Series
70
70 Series
71 Series
72 Series
74 Series
95
95 Series
91 Series
97 Series
98 Series
99 Series
100
100 Series
101 Series
105 Series
102 SERIES MULTISTAGE DIFFUSER NOZZLE RETENTION SYSTEM
REFERENCE
The multi-stage nozzle has an upper stage restrictor nozzle which controls the flow of the fluid through the nozzle and a
lower multi-orifice stage that distributes the flow onto the upper sections of the cones. The restrictor nozzle is
generally sized smaller than the diffuser nozzle. Typically the lower ports are oriented in the center jet so that the fluid
impinges on the top dead center of the cone. This method has been shown to provide superior cone cleaning as
compared to the standard center jet without any detrimental cone shell erosion. At the current time, Multistage
Diffusers are only available for bits with 100 series center jets. This is a standard center jet size for bits 16” and larger
but bits down to 9 ½” can be retrofitted with the 100 series center jet system.
81
NOZZLE TYPES AND APPLICATIONS FOR ROLLER CONE BITS
REFERENCE
Bit Size in.
Milled ToothSeries
Open Bearing
SealedBearing
Jet/AirSeries
ALL
TCISeries
Sealed/Journal Bearing
Full-Extended
Tubes
Q-Tubes
All Three-Cone Bits
Mini-Jets
MT TCI
CENTER JET RETENTION SYSTEMS
Bit Size RangeThree-Cone
Open BearingThree-Cone
Closed BearingTCT Bits
TCT,Two-ConeOuter Jets
CENTER JET COMPONENT LIST
82
3-1/8 - 5-1/2
5-7/8 - 6-3/4
7-3/8 - 7-5/8
7-7/8 - 8-3/8
8-1/2 - 8-3/4
9-1/2 - 9-7/8
10-5/8 - 12-1/4
13-1/2 - 14-3/4
16 - 28
70
95
95
95
95
95
100
100
55
70
95
95
95
95
95
100
100
70
95
95
95
95
95
55
70
95
95
95
95
95
100
100
70
70
95
95
100
100
70
70
95
95
100
100
72/74
97
97
97
97/98
105
105
72/74
98
98
98/99
98/99
105
105
6-1/8” - 6-3/4”
7-1/2” - 7-5/8”
7-7/8”
8-1/2” - 9”
9-1/2” - 14-3/4”
16” - 20”
22” - 28”
65
70 Long
70 Long
70 Short
95
100 Short
100 Long
70 Long
70 Long
70 Short
95
100 Short
100 Long
70 Long
70 Long
70 Short
95
100 Short
100 Long
SM
ITH
RO
LLER
CO
NE
BIT
NO
MEN
CLA
TUR
ET
CI
Series 4 5 6 7 8
FO
RM
AT
ION
S
5. S
EA
LE
D R
OL
LE
R B
EA
RIN
GG
AU
GE
PR
OT
EC
TE
D7.
SE
AL
ED
FR
ICT
ION
BE
AR
ING
GA
UG
E P
RO
TE
CT
ED
Types
So
ft F
orm
atio
ns/
Lo
w-C
om
pre
ssiv
eS
tren
gth
So
ft t
o M
ediu
m-H
ard
F
orm
atio
ns/
Lo
w-C
om
pre
ssiv
eS
tren
gth
Med
ium
-Har
d
Fo
rmat
ion
s/H
igh
-Co
mp
ress
ive
Str
eng
th
Har
d, S
emi-
Ab
rasi
ve
and
Ab
rasi
ve
Fo
rmat
ion
s
Ext
rem
ely
Har
d
and
Ab
rasi
ve
Fo
rmat
ion
s
SM
ITH
4 1 3 1 3
Hu
gh
es
Ch
rist
ense
nR
eed
-H
ycal
og
S
ecu
rity
D
BS
SM
ITH
4 2
Ro
ck
Bit
Co
mp
ari
so
n C
ha
rt
GS
i01B
,GS
01,G
S01
BG
S02
B,G
S02
T,G
S03
B
Gi0
3B,G
04B
,GS
04B
TC
Ti01
GS
05, G
S05
BG
Si0
6B, G
08B
, GS
08B
G10
B, G
10T
GS
10B
, GS
i12B
G
Si1
2UB
, TC
T10
GS
i15B
, G15
, GS
i18B
G
Si2
0B, G
11Y,
M15
S
15JS
G20
, GS
20B
, G25
G20
B, 2
0GM
S, 2
JSG
Si2
0B
G28
B
G30
, GS
30B
3JS
G40
, G40
Y, G
40Y
B
4JS
GT
X-0
0, G
X-0
0 M
AX
-GT
00, M
XL-
00
GT
X-0
3, G
X-0
3 M
AX
-GT
03, M
XL-
03
T41
E
MS
41H
XT
00-0
5 E
BX
T00
-05
GF
Si0
1, G
FS
04, G
FS
04B
M
FS
04, M
Fi0
4
GT-
00, M
X-0
0, G
T-03
M
X-0
3, G
X-0
0, G
X-0
3 S
TR
-03,
H-0
3 M
XL-
00, M
XL-
03
TD
41H
, TD
41
TD
41A
, R01
AR
03A
XS
00-0
5, X
L00-
05
EB
XS
00-0
5 E
BX
L00-
05
T42
E
MS
42H
XT
06-0
9 E
BX
T06
-09
GF
05, G
F05
B, G
Fi0
5BG
FS
i06,
MF
05B
ST
R-0
5C, H
X-0
5CT
D42
HR
07A
XS
06-0
9, X
L06-
09
EB
XS
06-0
9 E
BX
L06-
09G
TX
-09,
MA
XG
T-09
M
X-0
9, G
TX
-11,
MX
11M
X11
S, M
XL-
09
T43
E
MS
43A
E
MS
43H
XT
10-1
3 E
BX
T10
-13
F10
,F10
B,F
12,F
12Y,
GF
08B
GF
10B
, GF
10H
B, G
FS
10B
GF
12T,
XR
12,M
F10
T,M
FS
10T
XR
10T,
TC
T11
, TC
T12
GT-
09, S
TR
-09
ST
X-0
9, S
TX
-09H
HX
-09,
GX
-11,
MX
-09
MX
-11,
MX
11H
M
XL-
09, M
XL-
11
SL4
3H, T
D43
T
D43
A, T
D43
H
D43
, HP
43A
H
P43
H, R
09A
R
12A
, RD
12, R
14
XS
10-1
3, X
L10-
13
EB
XS
10-1
3 E
BX
L10-
13
MA
XG
T-18
M
X-1
8T
44
EM
S44
H
EM
S44
A
XT
14-1
7 E
BX
T14
-17
FH
16,F
H16
B,F
Hi1
8,M
F15
MF
15T,
MF
15B
,MF
19,G
F15
G
F15
B,G
F15
Y,G
FS
15B
X
R15
, XR
15T,
XR
i15G
GT-
18, S
TR
-18
ST
X-1
8, H
-18,
HX
-18
GX
-18,
MX
-18
MX
L-18
TD
44, T
D44
H
TD
44X
, D44
H
P44
H, H
P44
XR
14A
,RD
15R
15A
, R15
XS
14-1
7 X
L14-
17
EB
XS
14-1
7 E
BX
L14-
17
GT
X-2
0, M
AX
GT-
20
MX
-20,
MX
L-20
GT
X-2
2M
X-2
2
MX
-30H
M
AX
-GT
30
GT
X-3
0C, G
TX
-33
MA
X-G
T30
CG
MX
-33C
G
GT-
40C
, MX
-44C
MX
-55
T51
E
MS
51A
E
MS
51H
T52
E
MS
52H
T53
E
MS
53
EM
S53
A
ET
S53
A
T54
ET
S61
A
EM
S62
XT
18-2
3 E
BX
T18
-23
XT
24-2
7 E
BX
T24
-27
XT
28-3
3 E
BX
T28
-33
XT
34-3
9 E
BX
T34
-39
XT
40-4
5 E
BX
T40
-45
XT
46-5
1 E
BX
T46
-51
XT
52-5
8
F15
H, F
2, M
F2,
MF
15H
FH
i20,
FH
i21,
FH
i23,
GF
i20
GF
21, G
F25
, GF
S20
MF
S20
, XR
20, X
R20
B, X
R25
F25
Y, G
F20
Y, X
R20
Y,T
CTi
20
F3,
F30
, FH
30, F
30T
FH
i30,
FH
i31,
FH
32, G
F30
GF
30B
, GF
30T,
MF
30T
XR
30, X
R32
, F30
Y, F
H30
Y
FH
i35,
GF
i35,
F30
Y, F
37Y
FH
i37Y
,FH
i38Y
,F39
Y,G
Fi3
5YG
F37
Y, X
R30
Y, X
Ri3
5, X
R35
Y
GT
X-2
0C
MA
X-G
T20
CG
MX
-20C
, MX
-28G
GF
26, F
27, G
FS
28, F
Hi2
8G
Fi2
8B, F
Hi2
9, F
hi25
, F26
YM
F26
Y, F
Hi2
4Y, F
27A
, F27
IYG
F27
Y, X
R20
TY
GT-
20, S
TR
-20
ST
X-2
0, H
-20,
HX
-20
GX
-20,
MX
-20,
GX
-22
MX
-22,
GX
-23,
GX
-25
MX
L-20
ST
R-3
0, S
TX
-30
GT-
30, S
TX
-35,
GX
-30
H-3
0, H
X-3
0, M
X-3
0 M
XL-
30
GT-
20C
, GT-
28, H
-28
HX
-28,
GX
-20C
G
X-2
8, M
X-2
0C, M
X-2
8M
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