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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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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