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Table of Contents ®
IDEAS Technology
1-4
Applied Technology Technology
5 - 11
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Fixed Cutter Bits
12 - 31
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ARCS PDC Bi ARC Bits ts ™ SHAR SH ARC C PD PDC C Bit Bits s ® Ver ertiD tiDri rill ll PD PDC C Bits Bits ™ Shah Sh ahee een n PD PDC C Bi Bits ts ™ Kineti Kin etic c Dia Diamon mond d Impre Impreg g Bits Bits Standard PDC Bits Natural Diamond Bits PDC Cutter Technology Insert Technology Computational Fluid Dynamics - CFD Optional Features Fixed Cutter Nomenclature
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Roller Cone Bits
32 - 51
FH ® Gemini ® Sham Sh amal al Typ ypho hoon on ® Sham Sh amal al TN TNG G ® XPlorer
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XPlore XPlo rerr Ex Expa pand nded ed ™ TCT - Two-C Two-Cone one Techno Technology logy Roller Roller Cone Bits Standard Products ™ FlexFle x-Flo Flo Hyd Hydra rauli ulics cs ™ Typhoo yphoon n Hydr Hydraulic aulics s Insert Technology Optional Features Roller Cone Nomenclature
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52 - 55
BoreHole Enlargement
56 - 63
Percussion Hammers & Bits
64 - 69
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i-DRILL Drilli i-DRILL Drilling ng Simul Simulation ation Analy Analysis sis Advanced Services Engineering - ASE ® Drill Bit Optimization System - DBOS ® YieldPoint ™ Drilling Record System - DRS
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Turbodrills
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IMPAX Per IMPAX Percuss cussion ion Hammer Hammers s ® IMPAX IMP AX Pe Percu rcuss ssion ion Bit Bits s ™ DIGR DI GR Pe Perc rcus ussi sion on Bits Bits
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Reference Tools
70 - 84
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
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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
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IDEAS Technology IDEAS Technology Technology Ensures a Better Solution. The First Time, Every Time. 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 bit will perform for a specific drilling drilling program. Each customer is given an in-depth 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, 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, trajectory, weight on bit, lateral forces and lateral accelerations.
I D EA EA S ’ F i v e B a si s i c El El e m e n t s There are five basic elements to the bit design and performance advantages provided by IDEAS. •
Co m p r e h e n s i v e d r i l l i n g s y s t e m a n a l y s is i s : 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. assembly. •
H o l i s t i c d e s i g n p r o c e s s: s:
Smith Technologies Technologies design engineers account for every
critical variable to assure that IDEAS-designed bits are optimized optimized for performance. With the insight to bit performance provided provided by IDEAS, virtually every cone or cutter layout and configuration is designed to result in a stable bit that rotates around its center center,, the key to an efficient, optimized drilling operation.
1
®
IDEAS Technology IDEAS Technology Ensures a Better Solution. The First Time, Every Time. •
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. •
R a p i d So l u t i o n s w i t h R e l i a b l e Re s u l t s : 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 f or which they were designed. •
O p t i m i z e d I n t e g r a t i o n o f A d v a n c e d M a t e r i al s : 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.
Because the IDEAS process avoids the costly and t ime consuming t rial-and- error r equirement s of the t raditional drill bit design process, Smith Bit s can deliver a better solution, f aster.
2
®
IDEAS Technology ®
IDEAS Technology Ensures a Better Solution. The First Time, Every Time. Co n d u c t i n g v i r t u a l ca s e s t u d i e s 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 design
model
to
determine
the
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 t he 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 f or 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 f aster, longer bit runs with less stress on the BHA and rig equipment.
3
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IDEAS Technology IDEAS Directional Certification of Fixed Cutter Bits Improves Performance, Reduces Risk and Keeps Directional Wells on Target. 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.
4
Applied Technology Eclipsing All Other Drillstring Analysis Programs 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 labderived 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. bending
stresses
and
Excessive
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. chance
i-DRILL
to
focus
gives the client the 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.
5
Applied Technology Advanced Services Engineering Sm i t h ' s t e c h n o l o g y a n d e n g i n e e r i n g e x p e r t i s e i n c u s t o m e r s ' o f f i ce s 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.
P r o v i d i n g e x p e r t d r i l l b i t s e l e ct i o n 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.
6
Applied Technology Advanced Services Engineering P la n n i n g t h e w e l l 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 t ypes 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.
P o st W e l l A n a l y s i s 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 effi cient and economical drilling solution to the customer.
7
Applied Technology
TM
Drill Bit Optimization System D B OS™ d e l i v e r s a b e t t e r b i t p r o g r a m f o r a c h i e v i n g l o w e r c o st p e r f o o t d r i l l e d . 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.
T h e D B OS e v a l u a t i o n p r o c e s s 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 inf ormation. 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, weighton-bit, RPM, torque, dull bit conditions and other parameters. The results of this analysis provide design and application engineering feedback for continuous improvement.
8
Applied Technology
®
®
Yield Point Hydraulic Analysis O p t i m i z e d h o l e c l ea n i n g w i t h Y i e l d Po i n t s o l u t i o n s 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.
Y i e l d Po i n t R T f o r r e a l - t i m e a s se s s m e n t 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 t ransferred 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.
D a t a I n p u t t o Y i el d P o in t 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 i nformation 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.
9
Applied Technology Drilling Record System™ D RS Of f e r s t h e I n d u s t r y ' s B es t L i b r a r y O f Bi t R u n I n f o r m a t i o n 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.
10
Fixed Cutter Bits
ARCS
™
Extending the Limits A R CS - A l t e r n a t i n g R a d i u s C u r v a t u r e S t a b i l i z a t i o n 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.
ARCS combines multiple sized PDC cutting elements t o define a unique cutting structure governed by geometric relationships that optimize bit performance.
Through this use of multiple cutter
sizes, ARCS improves bit stability, ROP and cutter durability.
8-3/4” MAi513MSBPX
ARCS Nomenclature
M A i 5 1 3 Cutter Size (Largest) Blade Count i - IDEAS Certified A - ARCS Technology M/S - Matrix or Steel
Type MA613 MA616 MA619 MA816 MA819 MA913 MA916 MAi513 MAi619 MASi513 *
Size Availability 6-1/8” 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”
* ARCS Sharc Bit
13
™
SHARC
Smith High Abrasion Resistance Configuration SH A RC h i g h p e r f o r m a n c e b it s f o r t o u g h f o r m a t i o n s 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.
D r i l l i n g a b r a si v e f o r m a t i o n s Smith Bits has developed cutters that complement the SHARC design's capability for drilli ng 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.
Type
SHARC Nomenclature
MD S i 6 1 9 Cutter Size Blade Count i - IDEAS Certified
S - SHARC D - IDEAS Directional Certified M/S - Matrix or Steel
14
14-3/4” MDSi619HBPX
Size Availability
MDSi613 MDSi619 MSi416 MSi513 MSi516 MSi519 MSi611 MSi613 MSi616
5-7/8”, 8-3/4”
MSi711 MSi716 MSi816
5-7/8”, 6”
MSi1013
12”
14-3/4” 7-7/8”, 8-3/4” 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” 7-7/8” 7-7/8”, 8-3/8”, 8-1/2”, 8-3/4” 9-7/8”, 12-1/4”, 16”
VertiDrill
™
Drill Bits for Maintaining a Vertical Trajectory V e r t i D r i l l b i t s m a i n t a i n a v e r t i c al p r o f i l e i n f a u l t e d an d f r a c t u r e d f o r m a t i o n s w i t h o u t u s i n g c o st l y a c t i v e s t e er i n g s y s t e m s . 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
A v e r t i c al w e l l b o r e w i t h o u t e x p e n s i v e d i r e ct i o n a l t o o l s Wellbore deviation issues in vertical sections can result from numerous f actors; 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.
H ow i t w o r k s 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.
6-1/4” MV613LYPX
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.
VertiDrill Nomenclature
M V i 6 1 3 Cutter Size Blade Count i - IDEAS Certified
V - VertiDrill M/S - Matrix or Steel
Type
Size Availability
MV513 MV516 MV613 MV616 MV716
6-1/8” 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”
MVi616
7-7/8”
15
™
SHAHEEN
Consistently Delivering Superior Performance in Difficult -to-Drill Middle East Carbonate Formations Smith Bits developed SHAHEEN PDC bits specifically to swiftly and surely att ack hard carbonate formations unique to the Middle East. The Shaheen, or peregrine falcon, is noted for being t he 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
SHAHEEN is designed with the specific characteristics required to effectively drill Middle Eastern Carbonat es.
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.
So m e e x a m p l e s o f Sh a h e e n b i t s i n c l u d e : MSi1016VHBPX SDi616MHUBPX MTi913WUETBPXC MDi716LVPX SSi916HMBPX MDSi613LWBPX
16
KINETIC
™
Diamond Impreg Bits K i n e t i c d i am o n d i m p r e g n a t e d b i t s s et r e co r d s f o r R O P a n d f o o t a g e d r i l l e d . 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.
Open face for optimum clearing
Brazed in GHI
Kinetic Bit Configurations 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
Cast in GHI
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
Dedicated fluid port
resistance in this critical area. The bit designs incorporate innovative new cutting concepts, including increased blade heights that make
Central flow
Application tuned impregnated body material
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.
17
KINETIC
™
Diamond Impreg Bits P r o p r i e t a r y co m b i n a t i o n o f u l t r a - h a r d m a t e r i a l s 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 l ow ROP and reduced footage.
7-7/8” K705BPX 6” K505TBPXX 6-1/2” K507TBPXC
H i g h p e r fo r m a n c e w h e n c om b i n e d w i t h t u r b o d r i l l s 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.
Kinetic Nomenclature
K H 5 0 3 Profile (3 = Round, 5 = Medium Parabolic, 7 = Long Parabolic)
Product Line Iteration Blade Density (1 = Heavy, 9 = Light) H - Hybrid Cutting Structure K - Kinetic Line
18
Type
Size Availability
K503 K505 K507 K703 K705 K707 KH613 KH813 KH1013 KH1213
4-1/8” - 12-1/4” 3-3/4”, 6”, 6-1/8”, 14-3/4” 6-1/2”, 8-3/8”, 8-1/2” , 8-3/4”,12-1/4” 4-1/2” - 8-3/4” 6” - 12-1/4” 6”, 6-1/2”, 8-1/2” 6” 8-3/8”, 8-1/2” , 12-1/4” 8-1/2” 14”
Standard PDC Bits Matrix & Steel Fixed Cutter Bits 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.
17-1/2” S519
12-1/4” Mi616
Type
Size Availability
Mi413 Mi416 Mi419 Mi513 Mi516 Mi519 Mi613 Mi616 Mi619 Mi713 Mi716 Mi811 Mi813 Mi816 Mi913 Mi916 Mi919 Mi1016 S416 S422 S516 S519
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”
S522 S613 S616 S619 S716 S719 S816 S819 SD519 SDi613 SDi616 Si419 Si519 Standard Nomenclature Si613 Si616 Si619 Si819 Cutter Size Blade Count i - IDEAS Certified M/S - Matrix or Steel
M i 6 1 6
7-7/8” - 9-7/8” , 12-1/4” 12-1/4”, 17” 6-1/8” 7-7/8” - 8-3/4”, 12” , 12-1/4” , 14-3/4” 6” 6-1/8” - 6-3/4” , 10-5/8” - 17-1/2” 12-1/4”, 17-1/2” 7-7/8”, 12-1/4” 12-1/4”, 14”, 16” 16” 12-1/4” 6-3/4” 6” & 12-1/4” 8-1/2” & 12-1/4” 8-1/2”, 10-5/8”, 12-1/4” , 13-1/2” 14-3/4”, 16” , 17” & 17-1/2” 12-1/4” 16” 8-1/2”, 12-1/4” & 17-1/2” 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” 17-1/2” 13-1/2” 8-1/2” 8-1/2” & 12-1/4” 16” 12-1/4” 13-1/2” 23” & 24”
Type
Size Availability
M413 M416 M419 M509 M511 M513 M516 M519 M609 M613 M616 M619 M711 M713 M716 M809 M813 M816 M909 M916 M1609 MD519 MD611 MD613 MD616 MD619 MD813 MD816 MD819 MD913 MD916 MD919 MDi416 MDi513 MDi516 MDi519 MDi613 MDi616 MDi619 MDi713 MDi716 MDi719 MDi813
7-7/8”
MDi816
8-3/8” , 8-1/2”, 10-5/8”, 12-1/4”, 13-3/4”, 17-1/2”, 18-1/8” , 18-1/4”
6” - 7-7/8” 8-1/2” 3-3/4” 4-1/2” 4-3/4” , 4-7/8”, 6-1/8”, 6-1/4” , 7-7/8” 5-7/8” - 9-7/8”, 11-5/8”, 12-1/4” , 16” 6” - 9-7/8” , 12-1/4” 3-5/8” , 3-3/4”, 4-1/8”, 4-1/2” , 4-3/4” 6” - 8-1/2”, 11-5/8”, 12-1/4” 6-3/4” - 9-7/8”, 12-1/4” 7-7/8” - 17-1/2” 5-7/8” 8-1/2”, 8-3/4” , 9-1/2” , 12-1/4” 6” , 8-3/8” - 12-1/4” 6” , 6-1/8” , 6-3/4” 6” , 7-7/8” - 9” , 12-1/4” 16” 4-3/4” , 5-7/8” , 6” , 6-1/2” 8-1/2” 8-1/2”, 8-3/4” 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” 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” 8-1/2” - 14-3/4” 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”
19
NATURAL DIAMOND Natural Diamond Bits 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.
Diamond Types
6-3/4” D71 4-3/4” D66
Cube A Congo diamond, cubeshaped with fair abrasion and impact resistance.
West African - Premium Dodecahedron in shape with good impact resistance and excellent abrasion resistance.
Carbonado A naturally occurring, polycrystalline diamond, irregular in shape. Excellent impact resistance and good abrasion resistance.
Congo Round - Regular A round monocrystalline diamond with a rough, textured surface. Fair abrasion and good impact resistance.
Natural Diamond Nomenclature
D S T 1 2 XX - Formation Hardness (00 Harder / 99 Softer) ST - Sidetrack
D - Surface Set Diamonds
20
Cutter Size
Current Availability
D54
1-10 spc
6-1/8”
D66
1-10 spc
4-5/8”, 4-3/4”
D71
1-10 spc
6-3/4”
DST12
1-10 spc
5-7/8”, 6” , 6-1/8”, 6-1/2” 7-7/8”, 8-3/4”
PDC Cutter Technology Smith 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-ofthe-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.
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.
Sm i t h PD C Cu t t e r P er f o r m a n ce I m p r o v e m e n t
Relative Wear Resistance
Relative Impact Resistance
Wear Resistance
Impact Resistance
2003 - 2004
2005 - 2006
2007 - 2008
Smith Bits' position of PDC bit performance leadership is testimony to the success of our R&D efforts in cutter technology.
21
Insert Technology GHI (Grit Hot-Pressed Inserts) 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.
Uniform Diamond Distribution Optim ized Material Material Wear Rates
22
and
The revolutionary Smith Bits GHI is more durable th an conventional GHI GHI s, and will drill faster fas ter for a longer period period of tim e.
CFD Computational Fluid Dynamics (CFD) Ef f i c i e n t H y d r a u l i c s I n c r e a s e s P e r f o r m a n c e a n d Lo L o w e r s D r i l l i n g Co Co s t s Smith’s design engineers use computational 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 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 operators bits that will drill at the lowest possible cost per foot/meter foot/meter..
Using CFD to visualize flow patterns provides designers with a reliable platform to analyze the effects of design modifications on bit perform ance.
CFD analysis can can reveal any p otent ial problems wit h flow patterns and allows designers to optimize the bit design design for maxim um perform ance ance..
23
OPTIONAL FEATURES B Fe Fe a t u r e B ac a c k r e a m i n g Cu Cu t t e r s Feature:
Backreaming c ut utters
Advantage Adv antage::
Strategic place Strategic placement ment of cutters cutters on the upsid upside e of each blade to allow backreaming in tight spots to reduce potential of "bit sticking” while pulling out of the hole
Bene Be nefi fit: t:
Allo Al lows ws a deg degre ree e of of bac backr krea eami ming ng su suff ffic icie ient nt to condition a hole without major risk of gauge pad wear
C Fe a t u r e Co n n e c t i o n N o t A PI PI S t a n d a r d Feat Fe atur ure: e:
NonNo n-st stan anda dard rd co conn nnec ecti tion on,, inc inclu ludi ding ng bo box x connection
Advantag Adv antage: e:
Allows non-stan Allows non-standard dard box conne connection ction for a give given n bit size; Shortest possible possible length between between bit box and turbine or motor pin
Bene Be nefi fit: t:
Prov Pr ovid ides es st stab abil iliz izat atio ion, n, re redu duce ces s ho hole le sp spir iral alin ing g an and d provides additional gauge protection
D Fe Fe a t u r e D O G S l e e v e ( D r i l l i n g o n Ga u g e )
24
Feature:
Dog Sl Sleeve
Advant Adv antage age::
Mitiga Mit igates tes hol hole e spir spirali aling ng
Bene Be nefi fit: t:
Enhanc Enha nces es BH BHA A st stab abil ilit ity y an and d he help lps s ma main inta tain in in-gauge wellbore
OPTIONAL FEATURES E Fe a t u r e ( c o m m o n t o a l l b i t t y p e s ) Ex t e n d e d Ga Ga u g e L e n g t h Fea eatu turre:
Long Lo nger er gau aug ge th than an st stan and dar ard d
Advantage Adv antage::
Provides a means Provides means of incre increasing asing bit stabili stability ty and allows more area for gauge protection components
Bene Be nefi fit: t:
Enha En hanc nces es st stab abil ilit ity y and and im impr pro ove ves s hol hole e qua quali lity ty
H Fe Fe a t u r e L a r g e r t h a n S t a n d a r d T FA FA Feat Fe atur ure: e:
High Hi gher er nu numb mber er of no nozz zzle les s th than an st stan anda dard rd
Advantag Adv antage: e:
Higher nozzle Higher nozzle counts counts and/o and/orr added added fixed fixed ports ports to increase cleaning, cooling and cuttings evacuation with available hydraulic flows; Allows for higher flow rates with minimal increase in pump pressure
Bene Be nefi fit: t:
Optimi Opti mize zed d RO ROP P an and d bi bitt li life fe;; Lo Long nger er dr dril illi ling ng intervals without need for tripping
I Fe at at u r e I F Co n n e c t i o n Feat atur ure e:
Repl plac aces es sta tand nda ard co conn nnec ecti tio on
Advantag Adv antage: e:
Allows the bit to confo Allows conform rm to direc directional tional tools connection type
Bene Be nefi fit: t:
Prov Pr ovid ides es mo more re fl flex exib ibil ilit ity y in co conf nfig igur urin ing ga drilling assembly
25
OPTIONAL FEATURES K Fe a t u r e I m p r e g n a t e d Cu t t e r B ac k i n g Feature:
Diamonds impregnated in the matrix behind the PDC cutters
Advantage:
Limits the wear progress of PDC cutters
Benefit:
Increased footage drilled in abrasive applications
L Fe a t u r e L o w Ex p o s u r e 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
M Fe a t u r e Replaceable Lo-Vibe
26
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 N F ea t u r e Fe w e r N u m b e r o f N o z zl e s t h a n St a n d a r d Feature:
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
Q Fe a t u r e Co n t a i n s Fi x e d P o r t s Feature:
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
P X Fe a t u r e D i a m o n d En h a n c e d Ga u g e Pr o t e c t i o n 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
27
OPTIONAL FEATURES P XX Fe a t u r e Fu l l D i a m o n d Ga u g e P a d o n T u r b i n e Sl e e v e Feature:
Full diamond gauge pad on turbine sleeve
Advantage:
Diamond enhanced inserts to provide the greatest possible gauge protection in highly abrasive formations and underbalanced drilling
Benefit:
In-gauge hole and long gauge life in extreme drilling environments; Longer drilling intervals without need for tripping
R Fe a t u r e R es t r i c t o r Pl a t e i n t h e Pi n 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
S Fe a t u r e Sh o r t Ga u g e L e n g t h
28
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
OPTIONAL FEATURES T Fe a t u r e T u r b i n e Sl e e v e 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.
V Fe a t u r e Lo -Vi be TM Op t io n 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.
U Fe a t u r e Co n t a i n s 5 0 Se r i e s N o z z l e s 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
29
OPTIONAL FEATURES W F ea t u r e Co n t a i n s 4 0 Se r i e s N o z z l e s Feature:
Contains 40 series nozzles
Advantage:
Increase thread size for wear/erosion resistance
Benefit:
Reduced pop-up force when tightening the nozzle
Y Fe a t u r e Co n t a i n s 3 0 Se r i e s N o z z l e s Feature:
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
Z Fe a t u r e T SP o n L e a d i n g Ed g e ( K i n e t i c )
30
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 Nomenclature Product Line Prefix i Di A V S C HOX M S K H D L PR T ST SHO QD G R
Description IDEAS certified design IDEAS cer ti fi ed dir ec ti onal des ign ARCS & ARCS Advanced VertiDrill SHARC Carbonate Heavy Oil Series Matrix Body Steel Body Kinetic Impregnated Bit Kinetic Hybrid Bit Natural Diamond Bit LIVE Pilot Reamer Turbine Side Track Staged Hole Opener QUAD-D Dual Diameter Ream er s w it h API Co nn ect io ns (b ox do wn , p in up ) Ream er s w it h IF Co nn ec ti on s (<6 5/8" ) (p in do wn , b ox up ) Nomenclature Identifies Bl ade Count/Cutter Size Example: M616 = 6 Blades/16mm Cutters
Face Features L M V Z K
Hydraulic Features H N Y W U Q R
Gauge Features E S T D B PX PXX
Connection Features C I
Description Low Exposure Replaceable Lo-Vibe Lo-Vibe TSP on Leading Edge (Kinetic) Impregnated Cutter Backing
Description Higher Number of Nozzles Than Standard Lower Number of Nozzles Than Standard 30 Series Nozzles 40 Series Nozzles 50 Series Nozzles Fixed Ports Restrictor Plate
Description Extended Gauge Pad Length Short Gauge Pad Length Turbine Sleeve Dog Sleeve Back Reaming Cutters TSP on Gauge Full Diamond on Turbine Sleeve
Description Non API Standard Connection IF Connection
31
Roller Cone Bits
FH Optimized TCI Bits Set New Standards of Performance The 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.
Cu t t i n g S t r u c t u r e 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.
Reliability 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.
Hydraulics 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).
8-3/4” FH28GVPS
FH Nomenclature
7-7/8”
FHi20, FHi21, FHi21B, FHi23, FHi23U, FHi24Y, FHi26, FHi28 FHi30, FHi35, FHi38Y, FH40, FHi40, FH43Y, FHi45, FH50, FHi50
F H i 2 8
8-1/2”
FH23, FHi28, FHi28W, FH30, FH35, FH40, FH45, FH50, FHi90Y
8-3/4”
FH16B, FH16H, FHi18B, FH20, FHi20, FHi21B, FHi21UB FHi23B, FHi23U, FHi25, FHi25B, FH28, FHi28, FHi29, FHi30 FHi31, FH32, FHi35, FHi37HY, FHi38Y, FHi40, FH43Y, FH45 FHi50
9-7/8”
FH23, FH28, FH30, FH35, FH45, FH50HY
FH Designation
XX - Cutting Structure i - IDEAS Certified
12-1/4”
1
FH24Y, FH50
33
GEMINI Dynamic Twin Seal System 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
Gemini T w i n S e al System
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.
8-3/8” 8-1/2” 8-5/8” 8-3/4” 9-1/2” 11-5/8” 12” 12-1/4”
14-3/4” 16”
8-1/2” GF40H
17-1/2” 23” 24”
Gemini Nomenclature - Gemini bits incorporate a G in the prefix of the bit name.
34
26” 34”
GF15B, GF20, GF40B, GF45YB, GFi50YB GF08, GF10, GF15, GF15D, GF20, GF20D, GF25, GF25Y, GF30 GF30Y, GF40, GF40H, GF40YB, GF45Y, GF45HY, GF50Y, GF65Y GF80Y GF15 GF10, GF15, GF40 GF20, GF21, GF45, GFVH GF20 GF20 G04B, G04BD, GF05B, GF05BD, GF05W, GF10, GF10BD GF10HB, GF10HUB, GF15B, GF15BD, GF15HBD, GF20B GF20BD, GF20HB, GF26U, GFi28B, GF30B, GF30BD, GFi35B GF37U, GF37Y, GF47Y, GFi45, GGH+, MGGH+ G10B, G25, G25W G10B, G10BD, G18D, GGH+, MGGH+ G02B, G10B, G10T, G15B, G28B, G30B, GGH+ G08B, G12B G08B G08B MGG
SHAMAL Typhoon
™
The Power and Performance of the Perfect Storm 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. 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
Shamal Typhoon bit s incorporate t hree 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 incr eases ROP.
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” 17-1/2”
16” GSi12BVEJ3
1
GSi01B, GSi03B, GSi06B, GSi06UB, GSi12B GSi12UB, GSi15B, GSi18B, GSi20B GSi01B, GSi03B, GSi12B, GSi18B
22”
GS12B, GS12UB
28”
GS18B, GS18U, GS18UB
35
SHAMAL TNG Designed for Drilling in Carbonate Formations in the Middle East........And Beyond The Shamal TNG product line incorporates a range of tungsten carbide insert bits developed with direct input f rom 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.
8-1/2” 12”
12-1/4” GFS04B 12-1/4”
14-3/4” 15”
Shamal Nomenclature
15-1/2” 16”
G S i 0 5
17-1/2” 22”
Bearing Prefix
XX - Cutting Structure i - IDEAS Certified
Shamal Feature
36
23-1/2”
GFS05B, GFS06, GFS06H, GFS15, GFS30, MFS04 MFS10T, MFS20B GFS28HB GFSi01, GFS04B, GS04B, GFS05B, GFS05UB GS05B, GFSi06, GFS10B, GS10B, GFS11Y GFS15B, GS15B, GFS20B, GFS20UB, GFS26 GFS30 GS10B GS10B GS10 GS03B, GS05B, GS10B, GS18B, GS18UB, GS20B GS18UB, GS20B, GS20BD, GS26, GS30 GS03B, GS05B, GS05BD, GS10B, GS10BD, GS18 GS08, GS12B, GS12UB, GS12SD
26”
GS04B GS04B, GS18B GS04B, GS18
28”
GS18, GS18B, GS18U
24”
XPLORER Application-Focused Premium Slim Hole Bits 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.
Bearings
Forgings demanding
To handle the high rotation speeds typically seen in the formations in
directional program is achievable
which slim hole bits are used, a dual material Bullet™ seal system is used
with ultra short leg forgings that
for soft formation insert bits (IADC 4-1-7X to 5-4-7Y). This seal system
maximize steerability at extreme
reduces seal wear while at the same time limiting temperature build-up
build angles. The forging design also
through the use of matched, dual elastomers.
Even
the
maximizes
most
the
strength
of
the
chassis and meets the hydraulic demands
of
today's
drilling
programs.
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 t he 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.
Cu t t i n g S t r u c t u r e s 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.
3-3/4”
6-1/2” XR20T
3-7/8” 4-1/8” 4-1/2” 4-5/8” 12” 4-3/4”
Xplorer Nomenclature
X R i 2 0
4-7/8” 5-1/2” 5-5/8” 5-7/8” 6” 6-1/8”
Xplorer Designation
XX - Cutting Structure i - IDEAS Certified
6-1/4” 6-1/2” 6-3/4”
1
XR20Y XR30Y XR30 XR30 XR30 XR15, XR20, XR30, XR30Y, XR40Y, XR50, XR50Y XRi15, XR30 XR20W, XR30, XR30W, XR30Y, XR40Y XR15, XR30T XR15T, XR20T, XR30T, XR40Y, XR50Y, XR50YD XR10T, XR12, XR15T, XR20HT, XR20T, XR30T, XR30TY, XR40, XR40Y XR40YD, XR45Y, XR50, XR50W, XR50Y, XR65Y, XR70Y, XR70YD, XRH40Y XR10T, XR15T, XR15W, XR20HT, XR20T, XRSi20, XR20W, XR25, XR25W XR30T, XR30TY, XRi30, XRi30W, XRi35, XR38, XR40, XR40Y, XR50, XR50W XR50WY, XR50Y, XR60Y, XRi65Y, XR68Y, XR70Y, XR80Y, XR90Y XR20T, XR20W, XR30T, XR30Y, XR40, XR40Y, XR40YA, XR50, XR50Y,XRi35 XR15T, XR20T, XR30D, XR30T, XR30TY, XR40, XR40Y, XR40YA, XR45W XR50, XR50WY, XR50Y, XR68Y, XR70Y, XR90Y XR10T, XR25T, XR32T, XR32W, XR40, XR50
37
XPLORER Expanded Expanding the Performance Platform 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.
Flex-Flo
TM
The Xplorer Expanded bits are equipped with the Fl ex-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
Se a l s & B e a r i n g s 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).
Cu t t i n g S t r u c t u r e s
20” XR+CVPS
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 durabilit y.
Xplorer Nomenclature
X R + Xplorer Designation
38
XX - Premium Milled Tooth Cutting Structure
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”
XR+
TCT
™
Two Cone Technology for More Aggressive Roller Cone Designs 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 i ncrease 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 f ield 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 twocone 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
9-7/8” TCTi+
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.
TCT Nomenclature
6-1/2”
T C T i +
7-7/8” 8-1/2” 8-3/4”
XX - Premium Milled Tooth Cutting Structure
TCT Designation
1
i - IDEAS Certified
9-7/8” 12-1/4” 16” 17-1/2”
TCTi+ TCTi+20 TCTi+ TCTi+, TCT20, TCT37Y TCTi+ TCTi+, TCT11, TCT12 TCT+ TCT+, TCT10W
39
STANDARD PRODUCTS Milled Tooth, TCI and Open Bearing Bits 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 t he Spinodal journal bearing, a new bearing lubricant, the Flex-Flo Adaptive Hydraulics System, MIC2 hardfacing, diamond enhanced inserts, coarse carbide inserts and relieved gauge i nserts.
12-1/4” FVH
3-3/4” 6-3/4”
Standard Nomenclature/Milled Tooth Bits
6” 7-1/2” 7-7/8”
F V H
8-3/8” Heel Inserts Medium to Hard Formation Type
8-1/2” 8-3/4”
Bearing Prefix
8-7/8” 9-1/2” 9-7/8” 10-5/8” 11” 11-5/8” 12-1/4”
8-3/4” F12
Standard Nomenclature/TCI Inserts Bits
F 1 2 XX - Cutting Structure Bearing Prefix
40
14-3/4” 17” 17-1/2” 20” 22” 23” 26” 28”
OFH, OFM FDGH, FVH FDT FDS+, FI18, F26Y, F27Y, F27iY, F30Y, F37HY FI39HY, F45H, F47HY, F47YA, F49YA, F57Y F59HY, F67Y, F80Y, F85Y, F90Y MFDGH, SVH, F37Y, F57Y F10, F37HY, F37Y, F47HY, F57Y, F67Y, F80Y, F85Y FDGH, FDS+, MFDGH FDS+, F12V, F26Y, F27iY, F30T, F37HUY, F37HY F39HY, F40YA, F46HY, F47HY, F47YA, F50YA F59Y, F67Y, F80Y, F85Y, F90Y F40YA, F50YA FDS+ FDS+, F10B, F37Y, F47HY, F59Y, F67Y, F80Y F85Y, F90Y F37, F47Y, F67Y, F85Y, F90Y F20, F20Y, F27Y, F37Y, F47Y, FDS F30, F47Y, FDGH, MSVH F25Y, F37Y, F40, F47YA, F57, F67, F80Y, F90Y FDGH, FDS+, FDT F30 MSDGH DSJ MSDGH MSDGH DSJ, MSDGH DSJ, MSDGH MSDGH
Flex-Flo Adaptive Hydraulics TM
Superior Flexibility and Performance 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. ®
®
V-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.
X-FLO
(Cross Flow) - The many variations of XFlo allocate available hydraulic energy to improve penetration rates through both cone cleaning and dramatically increased impingement pressure needed for ultimate bottom hole cleaning.
®
S-FLO
(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.
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. H y d r a u li c F u n c t i o n v s . F o r m a t i o n ZONE 4
d e e
High strength formations that
N
ZONE 3
n o i t c n u F c i l u a r d y H
Medium strength formations that generate
volumes with hard TCI bits
moderate cuttings ZONE 2 ZONE 1
Very soft and/or sticky formations that generate very large volumes of cuttings with Milled Tooth bits and very soft TCI bits
1
generate low cuttings
Low strength
volumes with mediumhard TCI bits
formations that generate large cuttings volumes and drill with soft TCI bits
Cutting Structure Cleaning Bottom-Hole Cleaning Cuttings Evacuation
S o f t / S t i c k yH a r d /A b r a s i v e
41
Typhoon Hydraulics Unmatched Versatility Typhoon Hydraulics uses sophisticated CFD analysis techniques to evaluate fluid flow and ensure that flow is optimized to remove the cuttings more efficiently and t hat 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.
CFD analysis allows Smith’s engineers to optimize available hydr aulic energy t o m axim ize ROP.
42
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 cutt ings rem oval an d increases ROP.
Inserts I n s er t Op t i o n s 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
I ncisor
D o g Bo n e
ACE
Relieved Gauge Chisel
Chisel
Co n i c a l
that lower drilling costs.
Ge o m e t r y Ch o i c e s 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.
M a t e r i a l Ch o i c e s 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.
Coarse Carbide Microstructure
D i a m o n d Ch o i c e s Diamond Enhanced Insert
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.
1
43
OPTIONAL FEATURES B Fe a t u r e B i n a r y Ga u g e Pr o t e c t i o n Feature:
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
B D Fe a t u r e D i a m o n d En h a n c e d I n s e r t B i n a r y Ga u g e P r o t e c t i o n 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, ingauge bit runs
D Fe a t u r e D i a m o n d En h a n c e d Ga u g e R o w Inserts
44
Feature:
Diamond enhanced gauge inserts
Advantage:
Diamond enhanced inserts to significantly lower gauge row wear and breakage rates and provide greater 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 D D Fe a t u r e 1 0 0 % D i am o n d En h a n c ed 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 Fe a t u r e Su p e r D - G u n ™ Co n e Pr o t e c t i o n
1
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
45
OPTIONAL FEATURES O D Fe a t u r e D i a m o n d En h a n c e d H ee l Ro w I n s er t s Feature:
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
O D 1 Fe a t u r e A l l H ee l Ro w I n s e r t s D i a m o n d En h a n c e d 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 Fe a t u r e Sh a p e d D i am o n d Ga u g e I n s e r t s
46
Feature:
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
OPTIONAL FEATURES T Fe a t u r e T u n g s t e n Ca r b i d e T r u c u t ™ Ga u g e P r o t e c t i o n Feature:
Tungsten carbide Trucut gauge protection
Advantage:
A twin gauge element system composed of an aggressive, near-gauge insert to drill the neargauge 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
T D Fe a t u r e D i a m o n d En h a n c e d T r u c u t ™ Ga u g e P r o t e c t i o n Feature:
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 Fe a t u r e L u g T y p e L e g B ac k P r o t e c t i o n Feature:
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 P D Fe a t u r e D i a m o n d E n h a n c e d L eg B a ck Pr o t e c t i o n Feature:
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 [tungstencarbide only] leg back protection configurations
Benefit:
Extended bit life in extremely abrasive environments
P S Fe a t u r e Se m i - R o u n d T o p Tu n g s t e n Ca r b i d e I n s e r t L e g Ba ck P r o t e c t i o n 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 Fe a t u r e Se m i - R o u n d T o p Tu n g s t e n Ca r b i d e I n s e r t S t a b i l i za t i o n & L eg B a ck Protection
48
Feature:
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
OPTIONAL FEATURES C Fe a t u r e Ce n t e r J e t
Standard
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
Diffuser
J3 F ea t u r e ( D o m e Je t s ) ( A v ai l ab l e f o r 1 6 ” a n d l a r g er b i t s ) 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 and allow maximum ROP
Benefit:
Increased cone cleaning to prevent bit balling
V Fe a t u r e ™ V - Fl o N o zz le Co n f i g u r a t i o n
1
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
49
OPTIONAL FEATURES V E Fe a t u r e ( A v a il a b le f o r 1 2 - 1 / 4 ” a n d la r g e r bi t s )
50
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
Rock Bit Nomenclature Bearing/Seal Identifier & Product Line Prefix
Applies To:
Refers To:
D S F MF M K G GF XR TCT FH S
All All All All All All All All All All TCI TCI
Bearing/Seal Bearing/Seal Bearing/Seal Bearing/Seal Bearing/Seal Bearing/Seal Product Line Product Line Product Line Product Line Product Line Cutting Structure
i
All
IDEAS
+ DS DG S T G V S H B H T 00-99
MT MT MT MT MT MT MT MT MT TCI TCI TCI TCI
Cutting Structure Cutting Structure Cutting Structure Cutting Structure Cutting Structure Cutting Structure Cutting Structure Cu tti ng Stru ct ure Carbide Gauge Carbide Gauge Carbide Gauge Carbide Gauge Cutting Structure
Product Suffix
Applies To:
Refers To:
I W Y A N
TCI TCI TCI All All
Cutting Structure Cu tti ng Stru ct ure Cu tti ng Stru ct ure Cutting Structure Size
Feature
Applies To:
Refers To:
TD SD SD1 D OD OD1 DD DD2 G Q V E VE J3 C L LD R RD PS PD P
TCI TCI TCI TCI All All TCI TCI TCI All All All All All All All All A ll A ll All All A ll
Diamond Gauge Diamond Gauge Diamond Gauge Diamond Gauge Diamond Heel Diamond Heel Full Diamond Full Diamond Cutting Structure Hydraulics Hydraulics Hydraulics Hydraulics Hydraulics Hydraulics Leg Protection Leg Protection L eg Pro tecti on L eg Pro tecti on Leg Protection Leg Protection L eg Pro tecti on
Description
Non-sealed (open) bearing Single seal, sealed roller bearing Single seal, sealed friction bearing Single seal, friction bearing motor bit Single seal, roller bearing motor bit High temperature seals (geothermal applications) ® Gemini , twin seal, roller bearing ® Gemini , twin seal, friction bearing Xplorer ® (Milled Tooth bits up to 36"; Insert bits up to 6.75") TCT™ bits, Two-Cone Technology FH bits, single seal, sealed friction bearing ® Shamal or Shamal Typhoon design IDEAS certified design (lower case - 'i') Milled tooth designator / Premium cutting structure Soft type (IADC 1-1-X) - applicable to 'FDS' bits only Medium type (IADC 1-3-X) - does not apply to Gemini Soft type (formerly DS) - 'D' and 'G' products only Medium soft type (formerly DT) Medium type (formerly DG) - 'D' and 'G' products only Medium hard type (formerly V2) P remiu m se lf sha rpe ni ng ha rd facin g Non premium bit - heel inserts Binary carbide gauge Heavy set gauge design (count and or grade) Trucut gauge (carbide material on both off-gauge and gauge) Insert bit numeric range (00 Softest - 99 Hardest) Description Inclined chisel on gauge (upper case - 'I') S oft er t han stan da rd inser t gr ade s Co ni ca l i nsert cu tti ng st ructu re Air application bit Nominal gauge diameter
Description Trucut diamond inserts (diamond on gauge; carbide on off-gauge) Shaped diamond gauge and Diamond heel (20% to 50%) Shaped diamond gauge and Diamond heel (51% to 100%) SRT diamond gauge Diamond heel, (20% to 50% diamond) Diamond heel, (51% to 100% diamond) Diamond enhanced cutting structure (nose, middle and gauge inserts) Diamond enhanced cutting structure, (nose, middle and premium gauge inserts) Tungsten carbide cone shell protection (Super-D Gun) Q-Tube hydraulics V-Flo hydraulics Extended Nozzle Tubes Vectored Extended Nozzle Tubes Dome Jets (3 jets in the bit dome) Center jet Lug pads with tungsten carbide inserts Lug pads with diamond inserts Up pe r le gb ack SRT ca rbi de in se rt clu ste r a nd PS feat ure Up pe r le gb ack SRT dia mond insert cl uster an d PD fea ture SRT tungsten carbide leg protection SRT diamond leg protection Mo dif ied PS fea tu re patt ern ; No te: We st Te xa s bi ts on ly
NOTE: Black text appli es to MT and TCI. Blue text applies to MT only. Green text applies to TCI only
1
51
Turbodrilling
Turbodrilling Smith Neyrfor Turbodrilling-The Faster Way to Better Drilling Performance A H i s t o r y o f T e c h n i c a l Le a d e r s h i p 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.
Turbodrill Rotor/Stator Pair
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.
Th e Tu r b o d r i l l i n g A d v a n t a g e Smith Neyr for Turbod rills 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 straighthole drilling where supplemental power to improve drilling efficiency is the primary objective. En e r g y Ef f i c i e n c y : 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.
53
Turbodrilling Smith Neyrfor Turbodrilling-The Faster Way to Better Drilling Performance Po w e r O u t p u t : Superior energy efficiency of the
R el a t i v e P o w e r O u t p u t : T u r b o d r i l l v s . P D M
turbodrill translates directly into more power available at the bit to destroy the rock faster for higher rates of penetration.
r e w o P t u p t u O
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
PD M
tool increases, and the power output of the PDM
Turbodrill
degrades continuously throughout the run.
Time Downhole
Typical Operating Life
Re l i a b i li t y / O p er a t i n g L i f e : 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.
500 400 s r 300 u o H
200 100 0
V i b r a t i o n : Direct evidence of the superior vibration
Tu r b o d r i l l
PD M
characteristics of the turbodrill is available any time a turbodrill or PDM is surface-tested. The turbodrill
V i b r a t i o n : T u r b o d r i l l v s . PD M
appears virtually motionless as it hangs in the derrick being tested, while the PDM thrashes about violently as
14700
the effects of the unbalanced power section design become
all-too
apparent.
Downhole
dynamics
measurements routinely confirm this difference in
Vibration Level with PDM
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.
14800 h t p e D
14900
Vibration Level with Turbodrill
15000
High
54
Vibration
Low
Turbodrilling Smith Neyrfor Turbodrilling-The Faster Way to Better Drilling Performance H T H P Ca p a b i l i t y : 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.
D i r e c t i o n a l Ca p a b i l i t y : 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 f luctuating 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.
B o r e h o l e Q u a l i t y : 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 troublefree running of casing and a reduction in cementing costs because of the superior quality of the wellbore.
O p e r a t i n g Co s t : The ultimate advantage of a turbodrill is the
PDC Bearin g Assemb ly
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
Smith Borehole Enlargement
SBE Smith Borehole Enlargement Sm i t h B o r e h o l e En l a r g e m e n t c o m b i n e s l e ad i n g t e c h n o l o g i es a n d p r o d u c t s 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. ®
Rh i n o X S Re am e r e n l a r g es e x i st i n g o r p i l o t w e l lb o r e s 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.
57
SBE Smith Borehole Enlargement ®
R h i n o SS - S t a b i l iz a t i o n Sy s t e m ( R SS) 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 Diamond Enhanced Gauge I nserts
Z-Drive Tongue & Groove Actuation
Tungsten Carbide Hardfacing
58
Stabilizer Blocks Provide Concentric Stabilization
SBE Smith Borehole Enlargement I D EA S t e c h n o l o g y o p t i m i z es t h e p e r f o r m a n c e o f t h e e n t i r e d r i l l i n g a s s em b l y 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. ®
Re am a st e r f o r u n d e r r ea m i n g i n a l l d r i l l in g e n v i r o n m e n t s 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 t o 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
SBE Smith Borehole Enlargement H o l e Op e n e r s & U n d e r r e a m e r s 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.
Fixed Diamet er Hole Openers with O.D. less than 26” have 3 cutters
60
Fixed Diamet er Hole Openers with O.D. 26” or larger have 4 cutt ers
DTU w/ Bullnose
Rock-Type Underream er
™
QUAD-D
Dual Diameter Drift & Drill 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 bits were originally designed and developed by ! !
!
!
Drill-Out Capability Directional Responsiveness Diameter Control Design-Specific
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.
Type
16-1/2” x 20” QDS7313PX
QUAD-D Nomenclature
Q D S 7 3 1 3 Cutter Size Reamer Blades to Full Diameter Pilot Blade Count M/S - Matrix or Steel
QUAD-D Technology
Size Availability
QDM3209 QDM3309 QDM4209 QDM4213 QDM7309 QDM7313 QDMS4209 QDS3209 QDS4209 QDS5209 QDS5213
3-3/4” X 4-1/8” 5-7/8” X 6-1/2”
QDS5216 QDS5219 QDS6309 QDS7213 QDS7309 QDS7313
8-1/2” X 9-7/8”, 14-1/2” X 17-1/2” 17” X 20” 6-1/2” X 7-1/2”, 8-1/2” X 9-7/8” 12-1/4” X 14-1/4” 6” X 7”
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” 7” X 8-3/8” 8-1/2” X 9-7/8”, 12-1/4” X 14-3/4” , 14-1/2” X 17-1/2”
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”
61
QUAD-D
™ TM
Dual Diameter Drift & Drill - Reamer & GeoReam Products 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.
! !
!
!
Fishing Neck
Directional & BHA Flexibility Drill-Out Capability Diameter Control Design Specific
The QDR has drill collar connections for string placement
8-1/2” x 9-7/8” QDG5216 Tong Neck
8-1/2” x 9-7/8” QDR5313
10-5/8” x 12-1/4” QDR5313
6” x 7” QDG5316
QUAD-D Nomenclature
Q D G 5 3 1 6
Type QDG5216
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”
QDG5313 QDG5316 QDG7313 QDR5213 QDR5313
7-1/2” X 8-1/2”, 10-5/8” X 12-1/4”
QDR5319 QDR6313 QDRS5216 QDRS6313
16-1/2” X 19” 5-5/8” X 7-1/8”
Cutter Size Reamer Blades to Full Diameter Pilot Blade Count G / R - GeoReam or Reamer Product
QUAD-D Technology
62
Size Availability
6” X 7” 13-7/8” X 17” 12-1/4” X 14-1/2” 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”
16-1/2” X 20” 6-5/8” X 7-1/8”
SHO Staged Hole Openers 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.
St a g e O n e - P i l o t B i t !
!
!
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.
St a g e T w o - SH O P i l o t S e ct i o n !
!
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.
St a g e T h r e e - SH O P i l o t C o n d i t i o n i n g S ec t i o n ( P CS ) !
!
! !
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.
St a g e Fo u r - S H O Re a m i n g S ec t i o n !
8-1/2” x 12-1/4” SHO519
! !
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.
(shown inverted)
Type SHO516
Staged Hole Openers Nomenclature
S H O 5 1 9
SHO519 Cutter Size Blade Count
SHO - Staged Hole Opener
SHO716 SHOS516
Size Availability 8-1/2” X 10-5/8” 8-1/2” X 13-1/2” 9-1/2” X 10-5/8” 12-1/4” X 17-1/2” 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 16” 12-1/4” X 17-1/2” 12-1/4” X 17” 17-1/2” X 24”
63
Percussion Hammers & Bits
®
IMPAX
SMITH PERCUSSION
Percussion Hammers I m p a x h a m m e r i s d e s ig n e d f o r o i lf i e l d c o n d i t i o n s 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 v ibration, 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 b e tripped out of the well. Smith’s Impax hammers and Impax drill bits are a winning combination for superior reliability, durability and performance.
0
20
*ENHANCED INSERT
40
60
80
ft/lb
IMPAX 8 Percussion Hammer
65
®
IMPAX
SMITH PERCUSSION
Impax & DIGR Percussion Bits I m p a x b i t s p r o v i d e f a s t R OP a n d e x ce p t i o n a l d u r a b i l i t y 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.
I m pax bits feature industry's most reliable retention system 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.
D I GR™ B i t s ( D i a m o n d I n G au g e R o w ) The DIGR (Diamond In Gauge Row) line of hammer bits is the costeffective choice for drilling applications that do not require cutting structures with 100% diamond enhanced inserts. These bits offer a full range of cutting structure l ayout 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.
66
®
IMPAX
SMITH PERCUSSION
Hammer Bit Nomenclature
Hammer Bit Nomenclature Size (eighths)
Type
Available Features For Bit
061 062 063 064 066 077 083 084 086 086 087 087 094 095 096 097 105 110 122 123 146 174
H0806 H1006 H1006 H1006 H1006 H1209 H1209 H1209 H1206 H1209 H1209 H1512 H1509 H1509 H1509 H1509 H1509 H1209 H1209 H1209 H1812 H1809
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.
Current Features C D F G M N PD R T V X 6 7
Carbide Insert Diamond Enhanced Insert (DEI) Flat Diamond on Gauge Modified Non-Retainable Optional Gauge Protection Retainable Retainable “V” Thread Concave Convex Ø 6/8” (18mm) DEI (insert diameter) Ø 7/8” (22mm) DEI (insert diameter)
67
®
IMPAX
SMITH PERCUSSION
Hammer Bit Nomenclature Rope threads for secondary retention
New Spline Nomenclature New Spline Name Old Spline Name
Ingersoll Rand R04 R06 R08 R12 Q06 Q08 Q12 Q20 T09
Optional gauge protection
IR340 IR360 IR380 IR112 QL60 QL80 QL120 QL200 TD90
Typical spline design
Example: 086 H1512D
Numa N10 N12 N18
Face air holes
N100 N125 N180
Adjacent Gauge Insert
Gauge Insert
Mission M10 M12 M15 M18
SD10 SD12 SD15 SD18
Epley E12
Typical concave face design
E12000
Halco H06
H6
D
Example: 086 H1512D
086
H 15
12
G
Suffix = Diamond, Diamond on Gauge or Carbide
C Size
Prefix H = Hammer Bit
68
Descriptor = Number of Adjacent to Gauge Inserts Descriptor = Number of Gauge Inserts
®
IMPAX
SMITH PERCUSSION
Available Hammer Bit Features & Options Fa ce I n s e r t s :
B i t P r o f i l e Sh a p e s Co n t ’ d :
C Fe a t u r e - Ca r b i d e I n s e r t
V F ea t u r e - Co n c a v e
Feature:
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
Advantage: Provides additional drilling stability and directional control Benefit:
D Fe a t u r e - D i a m o n d En h a n c e d I n s e r t ( D EI ) Feature:
Concave bottom with a dual gauge angle bit head profile
All DEI cutting structure
Exceptional drilling performance in medium-soft to medium formation intervals where hole deviation is a primary concern
Advantage: Exceptional durability and abrasion resistance
X Fe a t u r e - C o n v e x
Benefit:
Feature:
Exceptional drilling performance in longer, hard formation intervals
6 Fe at u r e - ø6 / 8 ” ( 1 8 m m ) D EI 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
7 Fe at u r e - ø7 / 8 ” ( 2 2 m m ) D EI 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
Ga u g e I n s e r t s :
Flat-bottom with a dual gauge angle bit head profile
Advantage: Allows for utilization of heavy-set face and gauge cutting structures Benefit:
Exceptional drilling performance in medium to medium-hard formation intervals
B i t H e a d Re t e n t i o n : N Fe a t u r e - N o n - R e t a i n a b l e 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.
R Fe a t u r e – R e t a i n a b l e Feature:
Smith-patented bit head retention system (U.S. Patent 5,065,827)
G Fe a t u r e - D i a m o n d ( D EI ) i n G a u g e R o w
Advantage: Prevents the loss of the bit head in the hole
Feature:
Benefit:
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
Saves the cost of sidetracking or fishing
T Fe a t u r e - Re t a i n a b l e “ V ” T h r e a d Feature:
Slightly modified Smith patented bit head
Advantage: Allows bits with larger diameter shanks to be run with a ret ention system (U.S. Patent 5,065,827)
B i t P r o f i l e Sh a p e s :
Benefit:
F Featur e - Flat
Ga u g e Re i n f o r c e m e n t :
Feature:
P D Fe a t u r e - O p t i o n a l Ga u g e P r o t e c t i o n
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
M Fe a t u r e - M o d i f i e d Feature:
Non-standard bit head profile
Feature:
Saves the cost of sidetracking or fishing
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
Advantage: Unique geometry incorporated for specific operating parameters Benefit:
Enhanced performance for special drilling applications
69
Reference Tools
REFERENCE TOTAL FLOW AREA CHART 2
Total Flow Area (TFA) of Standard Nozzles (in. ) Number of Nozzles Nozzle Size (in)
1
2
3
4
5
7/32
0.038
0.075
0.113
0.150
0.188
8/32
0.049
0.098
0.147
0.196
9/32
0.062
0.124
0.186
10/32
0.077
0.153
11/32
0.093
12/32
6
7
8
9
10
0.225
0.263
0.301
0.338
0.376
0.245
0.295
0.334
0.393
0.442
0.491
0.249
0.311
0.373
0.435
0.497
0.559
0.621
0.230
0.307
0.383
0.460
0.537
0.614
0.690
0.767
0.186
0.278
0.371
0.464
0.557
0.650
0.742
0.835
0.928
0.110
0.221
0.331
0.442
0.552
0.663
0.773
0.884
0.994
1.104
13/32
0.130
0.259
0.389
0.518
0.648
0.778
0.907
1.037
1.167
1.296
14/32
0.150
0.301
0.451
0.601
0.752
0.902
1.052
1.203
1.353
1.503
15/32
0.173
0.345
0.518
0.690
0.863
1.035
1.208
1.381
1.553
1.726
16/32
0.196
0.393
0.589
0.785
0.982
1.178
1.374
1.571
1.767
1.963
18/32
0.249
0.497
0.746
0.994
1.243
1.491
1.740
1.988
2.237
2.485
20/32
0.307
0.614
0.920
1.227
1.534
1.841
2.148
2.454
2.761
3.068
22/32
0.371
0.742
1.114
1.485
1.856
2.227
2.599
2.970
3.341
3.712
24/32
0.442
0.884
1.325
1.767
2.209
2.651
3.093
3.534
3.976
4.418
71
REFERENCE DRILL COLLAR SPECIFICATIONS Drill Collar Weight (Steel) (lbs per foot) 1
2
3
4
5
6
7
8
9
10
11
12
13
14
3
3¼
3½
3¾
4
Drill Collar ID, inches
72
2½ 2
1¾
2
2¼
37
35
32
29
41
39
37
35
32
46
44
42
40
38
35
51
50
48
46
43
41
4-3/4”
54
52
50
47
44
5”
61
59
56
53
50
5-1/4”
68
65
63
60
57
5-1/2”
75
73
70
67
64
60
5-3/4”
82
80
78
75
72
67
64
60
6”
90
88
85
83
79
75
72
68
6-1/4”
98
96
94
91
88
83
80
76
72
6-1/2”
107
105
102
99
96
91
89
85
80
6-3/4”
116
114
111
108
105
100
98
93
89
7”
125
123
120
117
114
110
107
103
98
93
84
7-1/4”
134
132
130
127
124
119
116
112
108
103
93
7-1/2”
144
142
139
137
133
129
126
122
117
113
102
7-3/4”
154
152
150
147
144
139
136
132
128
123
112
8”
165
163
160
157
154
150
147
143
138
133
122
8-1/4”
176
174
171
168
165
160
158
154
149
144
133
8-1/2”
187
185
182
179
176
172
169
165
160
155
150
9”
210
208
206
203
200
195
192
188
184
179
174
9-1/2”
234
232
230
227
224
220
216
212
209
206
198
9-3/4”
248
245
243
240
237
232
229
225
221
216
211
10”
261
259
257
254
251
246
243
239
235
230
225
11”
317
315
313
310
307
302
299
295
291
286
281
12”
379
377
374
371
368
364
361
357
352
347
342
1
1¼
1½
2-7/8”
19
18
16
3”
21
20
18
3-1/8”
22
22
20
3-1/4”
26
24
22
3-1/2”
30
29
27
3-3/4”
35
33
32
4”
40
39
4-1/8”
43
4-1/4” 4-1/2”
13
/ 16
REFERENCE MEASUREMENT UNITS AND DRILLING FORMULAS Standard Measurement Units Quantity/Property Depth Weight-on-Bit
Units
Multiply By
To Obtain
Symbol
0.3048 0.445 4.535 x 10-4 32nds in. 0.794 ft./hr. 0.3048 barrels 0.1590 U.S. gal./stroke 3.785 x 10-3 U.S. gal./min. 3.875 x 10-3 bbls./stroke an oil barrel is 0.159873 x m3 exactly bbls./min. 0.1590 ft./min. 0.3048
meters decanewton tonne millimeters meters/hour cubic meters cubic meters/stroke cubic meters/minute cubic meters/stroke
m daN tonne mm m/hr. m3 m3/stroke m3/min. m3/stroke
cubic meters/minute meters/minute
m3/min. m/min.
in.
millimeters
mm
6.895 0.006895 0.06895 lbs./gal. (U.S.) 119.83 psi/ft. 22.621 secs./qt. (U.S.) 1.057 centipoise 1
kilopascals megapascals bar kilograms/cubic meter kilopascals/meter seconds/liters millipascal seconds
kPa MPa bar kg/m3 kPa/m s/l mPas
lb.f/100ft.2
pascals
Pa
millimeters cubic centimeters newton meters
mm cm3 Nm
ft. lbs.
Nozzle Size Drill Rate Volume Pump Output & Flow Rate
Annular Velocity & Slip Velocity Linear Length & Diameter Pressure
Mud Density Mud Gradient Funnel Viscosity Apparent & Plastic Viscosity Yield Point Gel Strength & Stress Cake Thickness Filter Loss Torque
25.4
psi
32nds in. mm or cc ft./lbs.
0.4788 (0.5 for field use) 0.794 1 1.3358
Drilling Formulas
Hydraulic Horsepower (Hhp) Hhp =
Cost per Foot (CPF) CPF =
Bit Cost + Rig Cost (Trip Time + Drilling Time) Footage Drilled
Pressure Drop ( ∆P) 2
∆P
=
Flow Rate x Mud Weight 10,856 x TFA
2
(Bit Pressure Drop) (Flow Rate) 1,714
Hole Area (Ah ) 2 π x Hole Diameter Ah = 4 Hydraulic HP per Square Inch (HSI) HSI =
Hydraulic Horsepower Hole Area (Sq. In.)
73
REFERENCE BUOYANCY FACTOR Buoyancy Factor Mud Density 3 (kg/l) (lb/gal) (lb/ft ) 1.00 8.35 62.4 1.02 8.51 63.7 1.04 8.68 64.9 1.06 8.85 66.2 1.08 9.01 67.4 1.10 9.18 68.7 1.12 9.31 69.9 1.14 9.51 71.2 1.16 9.68 72.4 1.18 9.85 73.7 1.20 10.01 74.9 1.22 10.18 76.2 1.24 10.35 77.4 1.26 10.52 78.7 1.28 10.68 79.9 1.30 10.85 81.2 1.32 11.02 82.4 1.34 11.18 83.7 1.36 11.35 84.9 1.38 11.52 86.2 1.40 11.68 87.4 1.42 11.85 88.7 1.44 12.02 89.9 1.46 12.18 91.2 1.48 12.35 92.4 1.50 12.52 93.7 1.52 12.68 94.9 1.54 12.85 96.2 1.56 13.02 97.4 1.58 13.18 98.7 1.60 13.35 99.9
Mud Density
Factor k
(kg/l)
(lb/gal)
(lb/ft )
Factor k
0.873 0.869 0.867 0.864 0.862 0.859 0.857 0.854 0.852 0.849 0.847 0.844 0.842 0.839 0.837 0.834 0.832 0.829 0.827 0.824 0.822 0.819 0.817 0.814 0.812 0.809 0.837 0.804 0.801 0.798 0.796
1.62 1.64 1.66 1.68 1.70 1.72 1.74 1.76 1.78 1.80 1.82 1.84 1.86 1.88 1.90 1.92 1.94 1.96 1.98 2.00 2.02 2.04 2.06 2.08 2.10 2.12 2.14 2.16 2.18 2.20 2.22
13.52 13.68 13.85 14.02 14.18 14.35 14.52 14.68 14.85 15.02 15.18 15.35 15.53 15.69 15.86 16.02 16.18 16.36 16.53 16.69 16.86 17.02 17.18 17.36 17.53 17.69 17.86 18.02 18.19 18.36 18.54
101.2 102.4 103.7 104.9 106.2 107.4 108.7 109.9 111.2 112.4 113.7 114.9 116.2 117.4 118.7 119.9 121.2 122.4 123.7 124.9 126.2 127.4 128.7 129.9 131.2 132.4 133.7 134.9 136.2 137.4 138.7
0.793 0.791 0.789 0.786 0.783 0.781 0.779 0.776 0.773 0.771 0.768 0.765 0.763 0.760 0.758 0.755 0.752 0.749 0.747 0.745 0.742 0.739 0.737 0.734 0.732 0.729 0.727 0.725 0.722 0.719 0.717
3
Apparent weight = Real Weight x Buoyancy Factor hence:
74
Buoyancy Factor (k) = 1
Mud Density Steel Density
REFERENCE FIXED CUTTER BIT NOZZLE INSTALLATION Correct Nozzle Installation Helps Prevent Washouts !
Remove the plastic plug and the O-ring from each nozzle port.
!
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.
Jet Nozzles Series 30 Series 40 Series 50 Series 60 Ports Steel Bits Matrix Bits
N 3 0 S e r i e s
Range (32nds) 7 - 13 7 - 13 7 - 16 7 - 22
Wrenches Series 30: 60007986 Series 40: 60018251 Series 50: 60024519 Series 60: 60003448 Vortexx 60: 60005675
Range (32nds) 8 - 12 8 - 16
O-Ring Series Series 30: 60007985 Series 40: 60007985 Series 50: 60019245 Series 60 / Vortexx 60: 60003276
N 4 0 S e r i e s
N 5 0 S e r i e s
N 6 0 S e r i e s
V o r t e x x 6 0
75
REFERENCE 6-5/8” API PIN RESTRICTOR NOZZLE 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
Figure 8
76
Figure 9
REFERENCE RECOMMENDED FIXED CUTTER BIT MAKE-UP TORQUE Recommended Make-Up Torque Diamond & Fixed Cutter Drill Bits With Pin Connections API Reg. Connection Size (inches)
2-3/8
2-7/8
3-1/2
4-1/2
6-5/8
7-5/8
8-5/8
Bit Sub OD (inches)
Minimum (ft-lbs)
Normal (ft-lbs)
Maximum (ft-lbs)
3
1,970
2,280
2,450
3-1/8
2,660
3,100
3,300
3-1/4
3,400
3,950
4,200
3-1/2
3,380
3,950
4,200
3-3/4 & Larger
5,080
5,900
6,300
4-1/8
5,700
6,600
7,000
4-1/4
6,940
8,050
8,550
4-1/2 & Larger
8,400
9,850
10,500
5-1/2
13,700
16,000
17,000
5-3/4
18,100
21,100
22,400
6 & Larger 7-1/2
18,550 40,670
21,600 47,300
22,900 50,200
7-3/4 & Larger
41,050
47,800
50,750
8-1/2
53,100
61,850
65,670
8-3/4
63,500
73,750
78,300
9 & Larger
68,600
79,800
84,750
10
96,170
102,600
108,950
10-1/4 & Larger
107,580
114,700
121,800
Notes: 1. Higher make-up torque values within the above ranges are recommended when high W OB is used. 2. Box connection bits should use make-up torque values between M i n im u m a n d N o r m a l . 3. All connections must be lubricated with a joint compound meeting A PI requirements.
77
REFERENCE FIXED CUTTER BIT FIELD OPERATING PROCEDURES T h e f o l lo w i n g g e n e r a l g u i d e l i n e s sh o u l d b e u s ed t o a v o i d b i t d a m a g e b e f o r e p l a c i n g a b i t i n t o s e r v i ce a n d t o e n su r e o p t i m u m p e r f o r m a n c e.
H o l e Pr e p a r a t i o n !
! !
Inspect previous bit for junk damage, lost 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.
Reaming !
!
Reaming long sections of under gauge hole is 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. ! !
B i t Pr e p a r a t i o n !
! !
!
! !
Use a rubber mat or wooden pad to set the bit 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.
Making Up th e Bit ! !
! ! !
!
Handle the bit with care. 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.
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Bit Break-in ! !
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Drilling Ahead !
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Tr i p p i n g i n t h e H o l e !
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Remove the breaker and carefully lower the bit through the rotary table. Trip slowly through BOPs, casing shoes and li ner 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.
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Lower bit to bottom with f ull flow. 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.
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Reduce rotary speed in abrasive or hard 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 f ollowing 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 weighton-bit, then increase rotary speed to previous rpm. Do not jam the bit back to bottom after making connections. !
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REFERENCE MAXIMUM CONE DIMENSIONS - For Three-Cone Rock Bits Size Range in. mm 1 7 89 - 98 3 /2 - 3 /8 3 4 /4 121 7 1 5 /8 - 6 /4 149 - 159 1 3 6 /2 - 6 /4 165 - 172 3 7 /8 - 8 187 - 203 1 1 8 /8 - 8 /2 206 - 216 5 8 /8 - 9 219 - 229 1 1 9 /8 - 9 /2 232 - 241 5 7 9 /8 - 9 /8 245 - 251 5 10 - 10 /8 254 - 270 7 11 - 11 /8 279 - 302 1 12 - 12 /4 305 - 311 1 13 /4 - 15 337 - 381 16 406 1 17 /2 445 1 18 /2 470 20 508 22 559 24 610 26 660 28 711
Maximum Diameter in. mm 3 2 /8 60 7 2 /8 73 1 4 /4 108 1 4 /2 114 1 5 /4 133 7 5 /8 149 1 6 /8 156 1 6 /2 165 3 6 /4 171 1 7 /4 184 7 7 /8 200 8 203 5 9 /8 244 1 10 /4 260 1 11 /2 292 12 305 1 12 /2 318 3 13 /4 349 1 15 /4 387 16 406 17 432
Maximum Length in. mm 5 1 /8 41 1 2 /8 54 1 3 /8 79 1 3 /2 89 4 102 1 4 /8 105 5 4 /8 117 3 4 /8 111 3 4 /4 121 1 5 /2 140 7 5 /8 149 1 6 /8 156 5 7 /8 194 1 8 /8 206 5 8 /8 219 9 229 5 9 /8 244 1 10 /2 267 1 11 /4 286 3 12 /4 324 13 330
APPROXIMATE BIT WEIGHTS Milled Tooth Approx. Weight lbs. kg 10 5 15 7 35 16 45 20 75 34 90 41 95 43 125 57 135 61 165 75 195 89 205 93 345 157 410 186 515 234 525 239 625 284 1,000 455 1,385 629 1,450 659 1,550 704
TCI Approx. Weight lbs. kg 12 5 20 9 45 20 55 25 85 39 95 43 100 45 130 59 145 66 175 80 210 95 225 102 380 173 450 205 545 248 570 259 700 318 1,170 532 1,400 636 1,550 704 1,650 750
RECOMMENDED ROLLER CONE BIT MAKE-UP TORQUE Size Range in. mm
API Pin Size
Recommended Torque ft.-lbs. N-m
in.
mm
89 - 114
2 /8 Reg.
3
60
3,000 - 3,500
4,000 - 4,800
118 - 127
2 /8 Reg.
7
73
6,000 - 7,000
8,000 - 9,500
137 - 187
3 /2 Reg.
1
89
7,000 - 9,000
9,500 - 12,000
1
194 - 229
4 /2 Reg.
1
114
12,000 - 16,000
16,000 - 22,000
1
241 - 711*
6 /8 Reg.
5
168
28,000 - 32,000
38,000 - 43,000
3
375 - 711*
6 /8 Reg. or 7 /8 Reg.
1
470 - 711*
7 /8 Reg. or 8 /8 Reg.
1
1
3 /2 - 4 /2 5
4 /8 - 5 1
3
5 /8 - 7 /8 7 /2 - 9 9 /2 - 28* 14 /4 - 28* 18 /2 - 28*
5
5
168 or 194
34,000 - 40,000
46,000 - 54,000
5
5
194 or 219
40,000 - 60,000
54,000 - 81,000
* Makeup torque m ust 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.
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REFERENCE NOZZLE COMPARISON CHART Jet Boss Series
Standard
Mini Extended Nozzles
Diverging
55 55 Series
70 70 Series
71 Series
72 Series
74 Series
95 Series
91 Series
97 Series
98 Series
100 Series
101 Series
105 Series
95
100
80
99 Series
REFERENCE 102 SERIES MULTISTAGE DIFFUSER NOZZLE RETENTION SYSTEM 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 1 00 series center jet system.
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REFERENCE NOZZLE TYPES AND APPLICATIONS FOR ROLLER CONE BITS Milled Tooth Series Bit Size in.
Jet/Air Series
Open Sealed Bearing Bearing
3-1/8 - 5-1/2
TCI Series
All Three-Cone Bits
TCT, Sealed/ FullJournal Two-Cone Extended Bearing Outer Jets Tubes
ALL
55
Q-Tubes
Mini-Jets MT
TCI
72/74
72/74
55
5-7/8 - 6-3/4
70
70
70
70
7-3/8 - 7-5/8
95
95
95
95
7-7/8 - 8-3/8
95
95
95
95
70
97
98
8-1/2 - 8-3/4
95
95
95
95
70
97
98
9-1/2 - 9-7/8
95
95
95
95
95
97
98/99
10-5/8 - 12-1/4
95
95
95
95
95
70
95
97/98
98/99
13-1/2 - 14-3/4
100
100
100
100
70
100
105
105
16 - 28
100
100
100
100
95
100
105
105
CENTER JET COMPONENT LIST CENTER JET RETENTION SYSTEMS Bit Size Range
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Three-Cone Three-Cone Open Bearing Closed Bearing
TCT Bits
6-1/8” - 6-3/4”
65
7-1/2” - 7-5/8”
70 Long
70 Long
70 Long
7-7/8”
70 Long
70 Long
70 Long
8-1/2” - 9”
70 Short
70 Short
70 Short
9-1/2” - 14-3/4”
95
95
95
16” - 20”
100 Short
100 Short
100 Short
22” - 28”
100 Long
100 Long
100 Long
