DBS_V2 Halliburton

So

lut

ion

S C

ata

log

SolutionS Catalog

Solving challenges.

1

table of Contents

Page 30

Roller Cone Drill BitsFixed Cutter Drill Bits

Page 12

DatCISM Process

Page 4

2

table of Contents

API Casing ChartMake-Up TorqueAPI TolerancesTFA ChartIADC Dull Grading

Hole Enlargement

Page 50

Coring Services

Page 44

References

Page 57

3

Safety

OSHA VPP Star Site

Safety is Fundamental to Halliburton

The Halliburton Drill Bits & Services manufacturing and technology facility in Conroe, Texas takes Halliburton safety fundamentals to another level by being recognized as a Star Worksite by the US Occupational Safety Health Administration (OSHA). OSHAs Voluntary Protection Programs (VPP) recognize and partner with businesses and worksites that show excellence in occupational safety and health. While all US companies must comply with OSHA regulations, the Star Program is designed for exemplary worksites with comprehensive, successful safety and health management systems. Our facility was recertified as a VPP Star Site in 2012, an honor the facility has held since its first certification in 2004.

Becoming an OSHA Star Site is not an easy accomplishment. It takes much more than a single audit or visit by OSHA personnel. Less than 1% of companies have been certified as OSHA VPP Star Sites, and Halliburton is the only drill bit manufacturer in the United States to receive this award. This repeated recognition demonstrates that safetyis top priority for Halliburton Drill Bits & Services.

As a public company with nearly 70,000 employees in approximately 80 countries, our number one priority is to offer safe and superior products and services. We promote safety and environmental principles by working together to protect our employees, stakeholders, communities and environment from harm.

Halliburton believes safety is everyones business. That is why every person at every worldwide location makes safety awareness their number one priority. Every member of every Halliburton team is tasked with taking personal ownership of his or her own safety and the safety of others.

Our goal is to keep our people (and the environments in which they work) safe and healthy. For this reason we put policies and procedures in place to make sure that adherence to proper safety practices is a 24/7 commitment on everyones part.

SPaRta Software

Direction by Design Software

Precise Bit Reamer (PBR)

MaxBHa Design Software

Performance Database

iBitS Software

CFD analysis

Drilling Roadmap

DatCISM Process

Every well is unique. With different applications around the world, there is no one-size-fits-all solution. Our unique DatCISM process takes that into account. Rather than centralizing design for drill bits, coring services, or downhole tools Halliburton Drill Bits & Services has highly trained Application Design Evaluation (ADESM) service specialists in locations around the globe. This enables us to work directly with customers to design application-specific solutions.

These deployed specialists integrate local knowledge with some of the industrys most powerful software, work-ing with customers to design drill bits and tools. Once designs are complete they are sent directly to manufac-turing, where drill bits are rapidly produced within industry-best cycle times. Because of our DatCI process, Halliburton is the North American market leader in drill bits.

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DatCiSM Process

Design at the Customer interface (DatCiSM) ProcessCustomized Drill Bits and Services engineered for optimal efficiency and performance

6

The DatCISM process is a continuous improvement loop employed by our on-location ADESM (Application Design Evaluation) service specialists to define application-specific drill bit solutions via well planning. This bit optimization process uses the industrys most powerful proprietary software tools and enables our specialists to predict bit performance and design the optimal bit for your specific objectives. We analyze formation properties to precisely define the application, and then match the bit design to that application.

Evaluate GeologyRefine Geo-model

SPARTA

Evaluate Offset DataPerformance Database

Identify Drilling Parameters PBR MaxBHA

Direction by Design

Optimize DesignIBitS CFD

RunDrilling Roadmap

Post Well EvaluationPerformance Reports

Capture Lessons LearnedCase History

Powerful Software- application Specific Solutions

Customer Challenge

DatCiSM ProcessDatCiSM Process

7

SPARTA software delivers advanced rock strength analysis and modeling, providing clear and concise information to optimize drill bit selection and drilling parameters. SPARTA helps to generate a map of anticipated geology including hard stringers, abrasive zones, and shales. This map can assist in optimizing drill-ing parameters to predict and evaluate run performance when plotted against offset wells. It can also be utilized for post-run evaluation to identify future bit selection and operating parameters. In a multi-well drilling pro-gram SPARTA software enhances the DatCI process, reducing cycle times and overall drilling costs.

SPaRtatM Software Scientific Planning and Real time applications

DatCiSM Process

Sandstone ShaleSilstone

Gamma Ray (api)

Density (g/cc)

ROP Avg (ft/hr)

MDft

MultipleLithology

LWD Calc. Density-Porosity (v/v)

Neutron-Density Porosity (v/v)

Neutron Porosity (v/v)

Density Porosity (v/v)

ConfinedRock Strength

lbs/ in2 abs

UnconfinedRock Strength

lbs/ in2 abs

Torque (ft lbs)

SPP (psi)

RPM (rpm)

WOB (klbs)

8

Halliburtons Direction by Design software provides advanced bit design engineering to optimize directional performance. Evaluating directional drill bit behavior depends greatly on understanding both the drive/steer mechanism and bit/formation interaction. Application Design Evaluation (ADESM) specialists use a wide variety of inputs such as applicable BHA configuration, operat-ing parameters, hole geometry, and formation charac-teristics to model bits for customer specific applications. Direction by Design software also allows Halliburton designers to define the connection between specific bit design features and their full impact on directional deliverables, enabling them to provide the ideal combi-nation of steerability, stability, and aggressiveness for the application. Either used as an application-specific bit selection tool or in conjunction with the DatCI process, this software is a powerful means to optimize matched bit design for the specific directional application and drive system. The result is fast, responsive directional drilling.

STRAIGHT HOLEDLS = 0

BUILD/DROPDLS = CONSTANT

KICK-OFF SIDE TRACKDLS CONSTANT

TARGET

Identifying optimum cutter back rake selection

Identifying optimum gauge length

Identifying optimum blade profile

Identifying hydraulics and cleaning configuration

The three Direction by Design software outputs are used to select and optimize bit features and dimensions to continuously drive enhanced performance in your unique directional application.

This continuous evolution replaces the traditional trial and error approach.

Designers simulate a range of bit actions and quantify the affect on steerability.

In this application, the bit is designed with a right-hand walk in order to offset a tendency toward undesired left-hand walk and remain centered on the well path.

Analysis of torque variance between different areas of the bit design allows maximum aggressiveness without over-engagement that can contribute to damaging vibration.

For a given bit under given drilling conditions, Direction by Design software determines the effects of bit geometry on steerability and walk rate, and calculates bit torque variance during directional drilling to account for different bit behaviors during kick-off, build and hold drilling modes.

Performance Evolution

Above, the ADESM specialist can isolate performance zones in each part of the directional trajectory, to focus on directional deliverables that are important in each zone.

Outputs

DatCiSM Process

Direction by Design Software

Side Force Output Bit Face Control Output Bit Walk Tendency Output

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Precise Bit Reamer software accurately simulates the interactions of bits, reamers, BHA and formation combi-nations. Precise Bit Reamer produces a simulation of drilling efficiency for each bit and reamer configuration, clearly showing the optimal combination. This capability supports both well planning and real-time decision making while drilling. PBR helps operators reduce non-productive time (NPT) and increase overall rate of penetration (ROP) when reaming while drilling.

Bit Reamer LogThe actual log excerpt from PBR (left) predicted that using a competitor reamer would produce excess vibrations, a prediction validated during the actual drilling.

The Performance Database is a global software system used to capture and analyze bit performance data. It provides accurate, valuable and fast information to aid sales, product development, and product manage-ment. The application allows Halliburton DBS field personnel to quickly and efficiently analyze bit performance data and provide our customers with tailored reports. As the system is constantly updated with new runs, Halliburton has the ability to understand the unique challenges present-ed by each play and see the trends of successful products. This gives our technology and product development teams the real-time feedback from the field required to be successful in developing our constantly evolving and improving product portfolio.

MaxBHATM is integrated BHA modeling and drilling optimization software for a wide range of applications in-cluding directional drilling, vibration reduction, survey improvement, and tool design optimization. It can also be used for well planning, realtime optimization, and postrun analysis.

Application Design Evaluation (ADE) service specialists run MaxBHA software with drill bit and reamer designs to gain insight on bending forces and to pinpoint critical rotary speeds for the BHA. The simulation software extends bit and reamer life by providing ADE service specialists with optimal run parameters that will minimize vibration and increase tool reliability.

DatCiSM Process

Precise Bit Reamer (PBR)

MaxBHa Design Software

Performance Database

MaxBHA application window

IBitSTM is a software tool is used by ADE service specialists to optimize bit selection or design a new bit for spe-cific applications. It enables Halliburton DBS to design the highest performing bits by simulating the forces that the bit will be exposed to under specific drilling parameters. IBitS software calculates the torsional, axial, and lateral forces of each cutting element depending on the cutting structure, geometry, and space position on the bit face. The sum of these forces (total bit force imbalance) is displayed as an output to indicate how the bit will perform in the application.

IBitS software can be used to rapidly design a drill bit in 3D. The ADE service specialists can collaborate in a customers office or at the rig site. Both the bit design and the manufacturing processes are generated simultane-ously. This process enables Halliburton DBS to achieve industry-best cycle times and manufacturing precision, which leads to best in class performance.

On the left, force balancing with radial and drag vectors. On the right, wear analysis factoring volume and footage drilled.

Optimal hydraulic configura-tions determined through unique modeling techniques in conjunction with Computation-al Fluid Dynamics (CFD).

A cutter tip profile shows a two dimensional representation of cutter spacing. Also, profile zones, attached to the cutter tip profile, depict how spacing, back rake, side rake, and degree of spiral are applied to the cut-ters along the profile.

IBitS software is used to create the manufacturing components and machining programs as well as the bit design.

Force/Energy BalancingHydraulicsCutter Layout Manufacturing

IBitS Software can be used to design arms and side wall protection for particu-lar applications for roller cone bits.

IBitS Software shows orienta-tion of compacts for energy balancing a roller cone bit.

Tooth angles are designed for roller cone bits with Energy Balanced technology.

The IBitS Software roller cone design shows bottom hole pat-tern (left), clearances between inserts (center) and insert spac-ing (right three).

Fixed Cutter Application Outputs

Side Wall ProtectionEnergy BalancingTooth Angles Insert Placement

Roller Cone Application Outputs

DatCiSM Process

iBitS Softwareinteractive Bit Solutions

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DatCiSM Process

Computational Fluid Dynamics analysis enables the designer to optimize nozzle placement and blade design for effective removal of cuttings. This reduces bit ball-ing and erosion thus maximizing bit life and ROP.

CFD analysisComputational Fluid Dynamics

As part of the DatCI process the drilling roadmap displays expected formations and provides bit and parameter recommendations as formations change. This translates into optimized ROP and bit life.

Drilling Roadmap

SHALE & SILTSTONESet rotary speed and weight to maintain maximum allowable

torque

WOB: 20 - 30Top Drive RPM: 60 - 80

Total RPM: 180maxROP: 100 - 600

> Through soft shales & siltstones RPMs can be increased and WOB can be decreased to optimize ROP within

allowable torque

Drill Bit Roadmap Example

Formation Details Drilling Parameters Additional Comments*** Drill out the 9 5/8 shoe slowly to ensure no damage to 8 3/4 bit.***

> May need to play within parameter ranges to optimize ROP



OSWEGOSlow when entering the LST

then can slowly increase WOB and optimize RPM

SHALE & SILTSTONESet rotary speed and weight to maintain maximum allowable

torque



COTTAGE GROVE SSTReduce rotary speed and slowly increase WOB to

maintain torque thru transitions



> Cottage Grove SST is interbedded with soft shale and siltstone so take care

drilling the transitions.

ARBUCKLESlow RPM and slowly increase

WOB to maintain ROP


Total RPM: 180maxROP: 40 -100

Please take care entering the Arbuckle, go slowly.

VIOLA & SIMPSONBoth formations have hard LST

interbedded with shale & siltstone



WILCOXNot all WOB will reach BHA

therefore drilling will depend more on Diff Pressure & RPMs



Wilcox is thick layer of SST with shale below so ROP should increase before entering the Arbuckle so TAKE CARE

ENTERING ARBUCKLE

> Reduce RPMs as bit approaches SST, once into SST increase WOB slowly to

maintain ROP



TONKAWA SANDSTONEReduce rotary speed and slowly increase WOB to

maintain torque

GOOD TORQUEBAD TORQUE

WOODFORD SHALEIn soft formation can slwoly back off WOB and increase

RPM



Woodford is a fast formation but need to be wary of the stringers and Misener SST

at end

MISSISSIPPI LSTNot a very thick section but take care with WOB & chert



Upper & lower Mississippi can contain varying amounts of chert

> Checkerboard can have LST, if so slow down RPMs and increase WOB through

any LST sections



CHECKERBOARDIf mostly shales increase RPMs and decrease WOB to optimize

ROP and torque

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Premium line

MegaForcetM Drill Bits

SteelForcetM Drill Bits

Performance line

FX SeriestM Drill Bits

iQ SeriestM Drill Bits

Fixed Cutter Drill Bits

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Proprietary technology development has produced the new thermally-stable and highly abrasion-resistant SelectCutterTM PDC technology, available exclusively in the premium drill bit product line from Halliburton. SelectCutter technology is suited to drill the most challenging formations by providing the highest level of abrasion resistance, impact resistance, and Thermal Mechanical Integrity available.

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High Imbalance Forcecreated by uneven distribution of cutting force as bit enters formation transition

Low Imbalance Forcecreated by even distribution of cut-ting force as bit enters formation transition

Standard Force Balanced Multi-Level Force Balanced

Impact Resistance measures the ability of a cutter to withstand a dynamic force without chipping or breaking, enabling the cutter to retain a sharp drilling edge for maximum rate of penetration.

Featured in our premium line of fixed cutter drill bits, our premium technologies incorporate all of the latest engineering advancements from our research and development labs.

3030 40 50 60 8070 90 10020

2003

2007 2010

2012

Impa

ct R

esist

ance

Abrasion Resistance

By optimizing cutter placement through Multi-Level Force Balancing, Halliburton premium bits provide the maximum bit stability and cutting structure efficiency during transitional drilling.

Thermal Mechanical Integrity (TMI) is the performance measure of a cutters capacity to endure frictional heat generated during the drilling process. Improving TMI means the cutters will wear slower because the diamond-to-diamond bonds can survive elevated temperatures prior to separating.

Abrasion Resistance measures the capability of a cutter to shear formation and minimize the loss of diamond. Improve-ments in diamond abrasion resistance main-tains the sharp cutting edge longer.

SelectCutter PDC Technology

Premium technologies

Multi-Level Force Balancing



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Halliburtons premium tungsten carbide matrix material offers a 20% improvement in erosion and wear resistance over our performance matrix mate-rial. This translates into maximum ROP by reducing the amount of cutting structure loss and allowing for longer intervals to be drilled by preventing bit body damage. New Matrix Material Previous Matrix Material

Green = Zero Material Loss Red = Material Loss (Erosion)

Halliburtons SteelForceTM premium line of steel body drill bits undergo a K1 Hardfacing treat-ment, rendering them virtually fracture proof and enabling them to be 100% abrasion resistant and 30% more erosion resistant than steel body drill bits with the previous hardfacing treatment.

As demonstrated in the photos to the right, the K1 hardfacing treatment creates a tighter arrangement of tough carbide pellets, providing maximum abra-sion and erosion resistance.

The use of targeted, directional micro nozzles in our premium line of drill bits optimizes fluid flow across the bit face. Micro nozzles permit significant increases in junk slot volume to improve cleaning at high ROP, re-duce chances of bit balling, and offer additional design flexibility for minimizing erosion and optimizing TFA (Total Flow Area).

Premium Tungsten Carbide Matrix Material

Current Hardfacing K1 Hardfacing

Standard Nozzles Micro Nozzles

The SteelForce premium line features anti-balling technology allowing for efficient drilling by maximizing the amount of cuttings removal. This pat-ented anti-balling nitriding treatment creates a lubricating water barrier between the bit body and the drilling mud.

The nitriding treatment creates a negative electrical potential in the surface of the steel, repelling the negative ions in the mud and creating a lubricating water barrier.

Premium Hardfacing (K1)

Anti-Balling Technology

Enhanced Hydraulics

Fixed Cutter Drill BitsFixed Cutter Drill Bits

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The Halliburton MegaForceTM bit features advanced SelectCutterTM PDC technology, ultra-efficient cutter layout force balancing, improved erosion resistant material and enhanced hydraulics. Designed for an operators specific application by one of our Application Design Evaluation (ADESM) service specialists using our industry-unique Design at the Customer Interface (DatCISM) process, the result is a matrix bit with a combination of higher ROP and longer intervals drilled than any other bit.

SelectCutter PDC TechnologyAllows the bit to stay sharper longer producing more footage at higher ROPs

Rockies: 20% Faster ROP and increased interval drilled

HalliburtonDBS77/8MM65HvsFX65

UnitahCountyUtah

Drilled31%morefootageata20% increase in ROP over the same section

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FX65 MM65H

Rate

of P

enet

ratio

n (ft

/hr)

Premium HydraulicsMicro nozzles optimize fluid flow across the bit face

Multi-Level Force BalancingProvides maximum bit stability and cutting structure efficiency during transitional drilling

Premium Tungsten Carbide MaterialHelps to reduce erosion and wear on PDC bit bodies

Optimal Shank LengthReduced bit length for directional control

MegaForce Drill Bitthe industrys Most Robust Matrix Body Bit


215210205200195190185180175170165160

FX65 MM65H

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FAMILY | CLASS CUTTER SIZE OPTIONAL FEATURES

BACKUP CUTTER (OPTIONAL)

APPLICATION PLATFORM (OPTIONAL)

BLADE COUNT

APPLICATION PLATFORM

(OPTIONAL)

CUTTER SIZE

FAMILY | CLASS BLADE COUNT BACKUP CUTTER (OPTIONAL)

ADDITIONAL CUTTER OPTIONS


5MM G 5 HMMegaForce Drill Bits


D = Directional (all other directional systems)

G = Geo-Pilot Rotary Steerable

E = Geo-Pilot EDL Rotary Steerable

T = Turbine High Rotational Speed

Not listed in nomenclature but found on marketing spec sheet. For more informa-tion, please contact your local Halliburton Drill Bits representative.

b = Back Reamingc = Carbide Reinforcemente = SE - Highly Spiraledf = Full PDC Gauge Trimmersk = Kerfing - Scribe Cuttersp = PDC Gauge Reinforcementu = Updrill

D = Dual Row Backup

M = Modified Diamond Round

R = R1 Backup Cutters

I = Impreg Backup Discs

C = Carbide Impact Arrestor

The blade count describes the number of blades on the bit.

3 = Three Blades

4 = Four Blades

5 = Five Blades

6 = Six Blades

7 = Seven Blades

8 = Eight Blades

9 = Nine Blades

The cutter size digit describes the size of the PDC cutters on the bit. On bits with multiple cutter sizes, the predominant size is described.

2 = 8 mm | 3/8"

3 = 10.5 mm | 13/32"

4 = 13 mm | 1/2"

5 = 16 mm | 5/8"

6 = 19 mm | 3/4"

8 = 25 mm | 1"

H = Highly abrasive wear

Highest penetration rates. Lowest cost per foot. Application-specific designs. With the Halliburton SteelForceTM bit, slow ROP due to bit cleaning is history. Taking drill bit design to a higher level, the SteelForce bit features a large flow area, anti-balling treatment, premium hardfacing, and micro nozzles to get the right flow to the right place on the bit face. Coupled with our industry-unique DatCISM process performed by one of our ADESM service specialists, our application-specific SteelForce bits are the best performing steel body bits to overcome your specific drilling challenges.

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800

900

1000

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1200

1300 051015202530354045

1217 20

43

3429

25 HDBS121/4SF56

Drilledentiresectionwith87% faster ROP over the field average

DullCondition1-1-WT

Interval Drilled

Inte

rval

Dril

led

ROP

Offse

t 1

Offse

t 2

Offse

t 3

Offse

t 4

Offse

t 5

FX56s

SF56

SelectCutter PDC TechnologyProvides the highest level of abrasion resistance, impact resistance, and Thermal Mechanical Integrity available

Higher Blade StandoffIncreases face volume for improved cuttings evacuation and higher rate of penetration

Premium HardfacingK1 harfacing is 100% more abrasion resistant, 30% more erosion resistant and includes tough carbide pellets making it virtually fracture proof

Anti-Balling CoatingHelps keep shale cuttings from balling and sticking to the bit by producing an electronegative charge, which repels the negative ions in shale cuttings

SteelForcetM Drill Bitthe industrys Most advanced Steel Body Drill Bit

ROP

17


Oman: 87% Faster ROP Over Field Average

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BLADE COUNT


(OPTIONAL)

CUTTER SIZE


SteelForce Drill Bits



5S F G 5 HM

H = Highly abrasive wear


Not listed in nomenclature but found on marketing spec sheet. For more informa-tion, please contact your local Halliburton Drill Bits representative.


D = Dual Row Backup



C = Carbide Impact Arrestor


3 = Three Blades

4 = Four Blades

5 = Five Blades

6 = Six Blades

7 = Seven Blades

8 = Eight Blades

9 = Nine Blades


2 = 8 mm | 3/8"

3 = 10.5 mm | 13/32"

4 = 13 mm | 1/2"

5 = 16 mm | 5/8"

6 = 19 mm | 3/4"

8 = 25 mm | 1"





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Since2008,X3 Series cutters have proven themselves over and over again as being high performing, long lasting cutters with high abrasion and impact resistance. Manufactured with new press technology,theX3 Series cutters have a high Thermal Mechanical Integrity (TMI) value and are able to withstand the frictional heat generated during the drilling process while limiting heat build-up.

ThehighperformingX3 Series cutters are an integral reasonwhytheFXSeries bits have drilled more than 100 million feet and counting day in and day out.

Halliburton specialists utilize the DatCISM process and our proprietary software to optimize cutter placement, hydraulicnozzles,anddefinebladegeometrytodesigntherightbitforyourapplication.TheFX Series bits are more efficient at removing cuttings from underneath the bit through advances in manufacturing and design technology.Thesebitsarecreatedfromamilledmold,allowingtheFXSeriesbitstohaveimprovedconsistencyand smoother drilling over hand formed molds used in previous generations of drill bits.

Featured in our performance line of fixed cutter drill bits, our performance technologies deliver proven value worldwide.

Therm

al

Mecha

nical

Integr

ity

Impa

ct

AbrasionPrevious Cutters

X3 Series Cutters

PreviousHand formed mold

CurrentComputer milled mold

X3 Series PDC Technology

Refined Blade Geometry

Performance technologies


20

With reduced bit body erosion, tungsten carbide matrix material increases the life of the bit.

Transverse Rupture Strength (TRS) is 18% higher in the current material opposed to the previous material.

The current carbide matrix material offers 50% more erosion resistance when compared to the previous material.

To limit flexing and prevent matrix material fracturing in our IQ line of diamond impregnated bits, our engineers designed bridges between the blades. Typically, blade height in a matrix type of bit is limited due to the low ductility of tungsten carbide. With the bridges in place, the overall strength and durability of the cutting structure is increased.

High quality synthetic diamond sintered with a dual phase binder provides a self-sharpening effect as the blade wears in our IQ line of bits. The soft bond phase allows for optimized diamond exposure while the hard bond phase prevents premature wear from abrasion and erosion.

Performance Tungsten Carbide Matrix Material


Matrix Bit Body Material

% D

iffer

ence

0%

20%

100%

40%

60%

80%

120%

140%

160%

TRS Erosion

Previous Materiial

FXMateriial

High Blade Standoff - Bridges

Intelligent Diamond and Binder Distribution

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FXSeriesTM drill bits are custom designed to overcome tough drilling challenges in even the harshest environments.IfreducingtriptimeisimportanttoyouthenanFXSeriesdrillbitistheanswer.HalliburtonsX3 SeriesTM cutter technology delivers a cutter that stays sharper, longer on a more erosion-resistant bit body. Ultimately, this means more footage drilled per bit and fewer trips for the operator.

X3 Series Cutter TechnologyAllows the bit to drill farther, faster because the cutters stay sharper, longer and are more durable under extreme drilling conditions

0

1

2

3

4

5

6

7

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200

300

400

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HDBS OFFSET 1 OFFSET 2 OFFSET 3

Series1

Series2

Footage RoP

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300

200

100DBS offset 1 offset 2 offset 3

Brazil: Interbedded Hard Rock in Carauari Formation

HalliburtonDBS81/2FXD74Ddrillbit

SingleRunon740meters(2828ft)

AverageROPof5.8m/hr(19ft/hr)

Outperformedalloffsetsintermsofboth footage drilled and penetration rate

FX Series Drill BitsProven Performers with over 100 Million Feet Drilled Worldwide

Refined Blade GeometryProvides added stability

Performance HydraulicsImproves cuttings removal and allows for more efficient cooling

Superior Bit Body MaterialReduces bit body erosion, increasing the life of the bit


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BLADE COUNT


(OPTIONAL)

CUTTER SIZE


FX Series Drill Bits

STEEL BODIED BITS

STEEL BODIED BITS

5F X G 5 sMNot listed in nomenclature but found on marketing spec sheet. For more informa-tion, please contact your local Halliburton Drill Bits representative.


s = Steel Bodied

D = Dual Row Backup



I = Impreg Backup Discs






3 = Three Blades

4 = Four Blades

5 = Five Blades

6 = Six Blades

7 = Seven Blades

8 = Eight Blades

9 = Nine Blades

0 = Ten Blades

1 = Eleven Blades

2 = Twelve or More Blades


2 = 8 mm | 3/8"

3 = 10.5 mm | 13/32"

4 = 13 mm | 1/2"

5 = 16 mm | 5/8"

6 = 19 mm | 3/4"

8 = 25 mm | 1"


IQ SeriesTM bits combine increased rates of penetration over longer intervals for enhanced drilling performance in a wide range of hard rock and HPHT applications.

As drilling becomes more complicated through deeper wells and harsh environments such as HPHT and hard and abrasive formations, Halliburton can help deliver these wells safely and at a lower cost using IQ Series, a proven and reliable impregnated diamond fixed cutter bit.

High Blade StandoffLends itself to giving more diamond volume to drill with during the run

Oman: Longest Single Impreg Run in Mabrouk Field

HalliburtonDBS6IQ610Ddrillbit

CompletedsectionuptoTD drilling 1016 meters (3,333 feet) in 2247.75 hrs

ROPof4.52m/hr(14.83ft/hr)

Lowestcostpermeterof$363/machieved versus$447/maverageCPMforthelast4wells 0

200

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600

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1000

1200

Offset 1 Offset 2 Offset 3 Offset 4 HDBSIQ610D

Offset 1

Offset 2

Offset 3

Offset 4

HDBS IQ610D

Met

ers D

rille

d

iQ Series Drill Bits

High Quality DiamondOctahedral synthetic diamond provides micro-aggressive cutting action

Intelligent Diamond and Binder DistributionThe binder ensures that the synthetic diamond is held in place until dull then it is released exposing a new diamond.

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High Diamond VolumeAllows the bit to stay sharper for a longer period of time


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1000

800

600

400

200

0Halliburton

DBSOffset 1 Offset 2 Offset 3 Offset 4

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FAMILY | CLASS CUTTER MACRO-GEOMETRY (OPTIONAL)


BLADE COUNT


FAMILY | CLASSBLADE COUNT

CUTTER MACRO-GEOMETRY (OPTIONAL)

15I Q 4 D


06 = Six Blades

07 = Seven Blades

08 = Eight Blades

09 = Nine Blades

10 = Ten Blades

11 = Eleven Blades

12 = Twelve Blades

13 = Thirteen Blades

14 = Fourteen Blades

15 = Fifteen Blades

1-3 = Soft

4-6 = Medium

7-9 = Hard & Abrasive

IQ Series Drill Bits S = Scribe Blocks

D = Drill Out Feature


Combining sophisticated design capabilities with the most advanced cutter technology, Halliburton Drill Bits & Services has created a series of PDC bit features to capture the benefits of durability and stability that are needed for any challenging application.

Fixed Cutter Bit Features

The Geo-Pilot PDC bit uses a Modified Extended Gauge (MEG) sleeve to give the box connection and fulcrum point necessary for the Geo-Pilot rotary steerable tool. The MEG sleeve gives consistent fulcrum point locations while maintaining a flow area from bit face to sleeve.

Geo-Pilot PDC Bit Design (G)

Directional PDC Bit Design (D)The Directional PDC bit uses different gauge and cutting structure geometries calculated from Direction by Design software to help ensure that adequate DLS and tool face can be achieved without sacrificing bit performance or life.


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Turbine PDC Bit Design (T)The Turbine PDC bit uses special cutter layouts and optimized Depth of Cut (DOC) to give maximum ROP in high RPM applications. Bits may utilize sleeves and extended gauges for stability or specialized gauge designs for directional applications.

Geo-PilotEDL Bit Design (E)The Geo-Pilot EDL PDC bit uses a standard point-the-bit cutting structure with a unique gauge design to allow high doglegs to be achieved.

BACKUP CUTTER

Use dual row SelectCutterTM orXSeriesTM cutters in highly abrasive applications where the bit ROP slows down and dull condition shows even wear.

Dual Row Backup Cutters (D)


27

Backup R1 Cutters (R)Use backup R1TM cutters when the application is highly interbedded with formations of significantly different rock strengths. Dull condition shows signs of cutter chippage in the nose and shoulder with surrounding cutters often having little to no wear.

Modified Diamond Reinforcement (MDR) cutters may be used as a diamond wear resistant axial arrestor or to replace the R1 backup cutter to minimize cutter pocket wear and mitigate the progression of ring out.

Modified Diamond Reinforcement (M)

Impreg Backup Discs (i)Use the i (synthetic diamond) backup cutter as a secondary cutter, allowing a dual cutting action with PDC and as a reinforcement to extend bit life. Typical applications are intermediate hard/abrasive formations (interbedded or not), high RPM applications, and exploration wells.


28

Use this feature to ensure that highly abrasive formations can be delivered at the maximum ROP and can achieve the longest run.

Available on MegaForceTM and SteelForceTM bits only.

Highly Abrasive Wear (H)


OPTIONAL FEATURES

Gauge Reinforcement (p)(Hex TSP, TSP, Dome PDC)

Impact Arrestor and Carbide Impact Arrestor (C)

Use TSP gauge elements in all applications except where gauge pad wear is observed. When extreme wear is observed, use Hex TSP or Dome PDCs.

Use Impact Arrestors and Carbide Impact Arrestors (CIA) when little wear is expected but impact damaged is observed. Ensure DOC guidelines are used.


Back Reaming Feature (Updrill, Back Reaming, Hybrid)

Directional Gauge Features (Drop-In, Full PDC Round, Stepped)

Use back reaming cutters when hole conditioning is needed and the top of the gauge pad has wear. When key seats or cave-ins are observed then use updrill cutters. When a combination of these events take place then use a hybrid set of back reaming and updrill cutters.

The standard is one drop-in cutter per gauge pad. Based on Direction by Design software, a more aggressive gauge may be required to achieve the DLS. In this case increasingly use more drop-in cutters per gauge pad, full PDC round cutters along the gauge pad or go to a stepped or undercut gauge pad as needed.

29

Kerfing - Scribe Cutters (k)The scribe cutter is a unique shaped PDC cutter that puts a maximum energy point load into the formation where crushing and fracturing the formation is more advantageous than shearing. This shape ensures that maximum ROP and rock removal can be achieved.


Roller Cone Drill Bits

QuadPack Plus Drill Bits

X Series Drill Bits

FracForce Drill Bits

31

Halliburton DBS roller cone bits have two main bearing configurations. Journal bearings (also called friction bearings) are used on all bit sizes ranging from 4 3/8 to 13 3/4 bits. Roller bearings are used on bits 14 1/4 to 28. Both the journal bearing and roller bearing geometries use our latest advancements in technology due to our proprietary bearing software program and in-house bearing tester. This combined with extensive field testing has resulted in our latest generation bearings.

Whether offshore drilling a 28 section or a slim hole application on land to reach TD, roller cone drill bits from Halliburton Drill Bits & Services provide solutions to customers globally. Whatever the drilling challenge: hard rock, highly interbedded, high chert content, high abrasion or high build rates Halliburton DBS roller cone bits are designed to withstand harsh drilling environments.

4 3/8 to 13 3/4 For bit sizes 4 3/8 to 13 3/4 the performance bearing uses a primary seal that exhibits greater thermal properties and wear resistance over its predecessor. This makes the performance bearing more effective in preventing contamination which extends bit life, resulting in better performance. A dedicated pressure compensation system which helps achieve pressure equalization across the bit is also used.

14 1/4 to 28Available in two configurations for 14 1/4 to 28. The performance bearing uses a primary seal along with an axial secondary seal as its bearing sealing system. The secondary seal works to protect the primary inner seal from cuttings debris and allows for pressure relief between the inner and axial seals. The premium bearing functions with a dedicated pressure compensation system.

8 1/2 to 28Available in sizes 8 1/2 to 28, the premium bearing uses two primary seals with a patented dual compensation system to extend bearing life. This dual system is a superior method for extending the life of the inner primary seal and reducing wear by preventing the intrusion of formation cuttings. Each primary seal has a dedicated reservoir to equalize pressure between them for maximum performance and life.

Roller Cone technologies

Bearings

Premium Bearing System

Performance Bearings


Optimized Contact Pressure Seal

A responsive Mechanical Pressure Compensator (MPC) system significantly reduces differential pressure variation on the seal. This equalizes pressure inside and out, which greatly diminishes seal stress and enhances the durability of the bearing/seal system. The rubber diaphragm system is quick acting in achieving pressure equalization.

There are now integrated mechanical relief compensation systems on all 4 3/8 to 28 sized bits.

Only Halliburton DBS offers this patented feature, a cutting structure which is balanced to equalized load and rock removal among all three cones. This is accomplished by optimizing cutter placement and analyzing the depth of cut on adjacent cutters. The result minimizes vibration which enhances the service life of sensitive instrumentation and equipment while increasing ROP and durability.

SupremeTech Hardfacing

At left, some cones bear more load than others, causing imbalance. At right, the load is balanced equally among all cones through use of Energy Balanced Technology.

SupremeTech - 73% improvement in wear resistance

Diamond TECH2000TM

32

By re-engineering the seal shape, we were able to deliver a 53% increase in seal reliability, a 24% reduction in torque friction, and a 16% decrease in temperature endured by the seal over the previous design. This was accomplished by moving the highest contact pressures to the edge of the sealing interface where it is needed most. In turn, the lower contact pressures at the center of the sealing face reduce wear and frictional torque.

Mechanical Pressure Compensator (MPC)

Energy Balanced Bit Technology

Our patented SupremeTechTM Hardfacing treatment pro-duces a material that is 73% more abrasion resistant com-pared to conventional hardfacing treatments. This abrasion resistance is achieved by using novel low-binder sintered-hipped tungsten carbide pellets. This helps maintain their super dense microstructure and superior roundness when compared to conventional hardfacing using high-binder sintered tungsten carbide pellets.


33

With the complexities and challenges of drilling in todays environment, Halliburton Drill Bits & Services has developed a line of roller cone bits well suited for these applications. QuadPack Plus drill bits are lowering operators cost per foot globally through better durability and performance.

The QuadPack Plus design profile is focused on removing cuttings from crucial areas of the cutting structure and wellbore, accomplished by changing the arm geometry. Directing nozzles towards the leading edge of the cutting structure to create directed flow channels is also done. This action produces higher ROP and extends the bit life when compared to traditional arm profiles. QuadPack Plus bits are available in sizes 4 1/2 to 13 3/4.

Increased Bearing CapacityAn increase in main bearing length results in optimized load distribution over the main bearing extending bit life

HalliburtonDBS12-1/4EQH26Rdrill bit

Drilled2,610feet(795meters)in26.5 hours

ROPof98.5ft/hr(30m/hr)

Outdrilledthecompetitoronthe same pad (20 feet away) in both footage and ROP EQH26R Offset

Forging DesignThe larger, more robust arm results in greater durability, improved protection and larger reservoir for increased grease capacity

More Responsive Pressure Compensation SystemSignificantly reduces differential pressure variation on the seal

Greater Seal Reliability53% increase in seal reliability, a 24% reduction in torque friction, and a 16% decrease in temperature endured by the seal over the previous design

QuadPack Plus Engineered Hydraulic Bits


3500

3000

2500

2000

1500

1000

500

DEP

TH

70.075.080.085.090.095.0100.0

65.060.055.050.0

Ohio: Fastest ROP and Lowest Cost Per Foot

34

FAMILY | CLASS

OPTIONAL FEATURES

CUTTING STRUCTURE (PREFIX)

CUTTING STRUCTURE

CUTTING STRUCTURE

ENERGY BALANCED BITS

FAMILY | CLASS CUTTING STRUCTURE

OPTIONAL FEATURES

QH = QuadPack Plus Engineered Hydraulics Bits (4-1/2" through 13-1/2")

OPTIONAL FEATURES

CE QH 1 LSFor more information, please contact your local Halliburton Drill Bits representative.

A = Air Application

C = Center Jet

D = Diamond Surf Row (33%)

D2 = Diamond Surf Row (50%)


G = Non-Standard Gauge Row

L = Lug Pads

LD = Diamond Insert Lug Pads

P = Protective Carbide Coating

R = Raised Enhanced Shirttail / Arm Protection

S = Enhanced Shirttail Protection

SD = Shirttail Diamond Enhanced Protection

RD = Shirttail Diamond Raised Protection

C = After Class Alpha for Claw Tooth on Steel Tooth Model D = For Gauge/Face Diamond Insert on Insert Model

For Tooth Bits Single Numeric Variant From 1 to 7 For Insert Bits Dual Numeric Variant From 00 to 99


E = Energy Balanced Bits

CUTTING STRUCTURE



OPTIONAL FEATURES

OPTIONAL FEATURES

DE QH 4 0 LS

INSERT BITS

TOOTH BITS


OurlineofXSeriesTM roller cone bits include non-sealed and sealed roller bearing bits, typically in sizes larger than 13-1/2. Featuring greater seal reliability, these bits ensure maximum performance to meet challenging applications.

Saudia Arabia: Record ROP and Cost Per Foot

HalliburtonDBS22EBXT02S

Drilled1,855feet(795meters)in33 hours

ROPof53.2ft/hr(30m/hr)

25.4%improvementinROPand reduction in cost per foot of 8% over the best competitor offset in the Shedgum field

Increased Bearing CapacityNew bearing has increased load capacity with larger cross section seals for increased compression while maintaining similar contact pressure

More Responsive Pressure Compensation SystemSignificantly reduces differential pressure variation on the seal

Greater Seal Reliability53% increase in seal reliability, a 24% reduction in torque friction, and a 16% decrease in temperature endured by the seal over the previous design

60

50

40

30

20

10

0

56.2

ROP

(ft/h

r)

54.7

Halliburton DBS Offset 1 Offset 2

41.9

20.9

X Series Drill Bits

35


FAMILY | CLASS

OPTIONAL FEATURES

CUTTING STRUCTURE (PREFIX)

CUTTING STRUCTURE

CUTTING STRUCTURE



OPTIONAL FEATURES

XN = Non Sealed Bearing XT = Sealed Roller Bearing

OPTIONAL FEATURES

CE B X T 1 LSENERGY BALANCED BITS

EB = Energy Balanced Bits

36


For more information, please contact your local Halliburton Drill Bits representative.

A = Air Application

C = Center Jet

D = Diamond Surf Row (33%)



G = Non-Standard Gauge Row

L = Lug Pads

LD = Diamond Insert Lug Pads

P = Protective Carbide Coating

R = Raised Enhanced Shirttail / Arm Protection


SD = Shirttail Diamond Enhanced Protection

RD = Shirttail Diamond Raised Protection

C = After Class Alpha for Claw Tooth on Steel Tooth Model D = For Gauge/Face Diamond Insert on Insert Model

For Tooth Bits Single Numeric Variant From 1 to 7 For Insert Bits Dual Numeric Variant From 00 to 99

37

FracForceTM roller cone tooth bits are designed for effective drill out of frac plugs once zonal isolation and stimulation is completed. They are suited for both coiled tubing and workover rigs when frac plugs require drill out.

The FracForce series helps save operators money by reducing rig time typically wasted using inefficient junk-mill bits. With an aggressive cutting action to reduce drilling time per plug and durability features to eliminate the need to trip and replace bits, the FracForce series is the solution for your drill out challenges.

Texas: Set Record for Operator in Eagle Ford

HalliburtonDBS41/2FracForcedrillbit

Drilledentiresectionof21plugsin11.5hours

Drilled8,460feet(2,579meters)

Performance Bearing and Seal ConfigurationUses a primary seal that exhibits greater thermal properties and wear resistance over its predecessor

SupremeTech Hardfacing73% more abrasion resistant compared to conventional hardfacing treatments

Bit Type Depth In Depth Out Footage Hours

4 1/2FF2 6,380 14,840 8,460 11.5

FracForcetM Drill Bits


38

FAMILY | CLASS

Cutting Structure

FAMILY | CLASS OPTIONAL FEATURES

CUTTING STRUCTURE

FracForce Drill Bits Optional Features

F F 2 RFor more information, please contact your local Halliburton Drill Bits and Services Representa-tive.

R = Raised Enhanced Shirttail/ Arm Protection



For tooth bits single numeric variant from 1 to 4.

Roller Cone Bit Features

The patented claw feature delays the typical wear pattern of the tooth leaving a longer sharper tooth for improved ROP and cutting structure life. Utilization of the Claw increases the aggressiveness of the bit as the teeth wear.

After Class Alpha for Claw Tooth on Steel Tooth Bits (C)

For Gauge/Face Diamond Insert on Insert Bits (D)Diamond enhanced gauge row insert protection for reduced gauge wear, high quality wellbore and improved cutting structure performance.

Cutting StRuCtuRE

39


40

Center Jet (C)Center jet feature to enhance cone cleaning and hydraulic flow patterns which helps prevent bit balling.

33% diamond surf protection improves resistance to impact damage and abrasive wear which results in more protection for the bearing seal extending bit life.

Diamond Surf Row 33% (D)

Air Application (A)Center bore in bit for air drilling applications which helps minimize the volume of drilling fluids needed for the full well and reduces the time that fluids are held in reserve pits.

oPtional FEatuRES


41

Diamond Surf Row 100% (D3)100% diamond surf protection improves resistance to impact damage and abrasive wear which results in more protection for the bearing seal extending bit life.

Non-Standard Gauge Row (G)

Lug Pads (L)

Tungsten carbide surf inserts in gauge teeth for added gauge protection.

Integral stabilizer pads for improved directional performance on steerable assemblies.

50% diamond surf protection improves resistance to impact damage and abrasive wear which results in more protection for the bearing seal extending bit life.

Diamond Surf Row 50% (D2)


Protective Carbide Coating (P)Thermalsprayprocess(HVOF),usingpatentedX-Gun,produces hard, dense tungsten carbide coatings for cutting structures that are resistant to abrasive wear and erosion.

Raised Enhanced Shirttail/Arm Protection (R)

Enhanced Shirttail/Arm Protection (S)

Raised tungsten carbide inserts and proprietary hardfacing provides maximum arm protection in abrasive and directional applications.

Shirttails protected with proprietary hardfacing and tungsten carbide inserts for maximum abrasion resistance.

Diamond Insert Lug Pads (LD)Diamond integral stabilizer pads for improved directional performance on steerable assemblies.

42


Shirttail Diamond - Raised Protection (RD)Raised diamond enhanced inserts and tungsten carbide inserts protect shirttail for maximum abrasion resistance.

Shirttail Diamond - Enhanced Protection (SD)Diamond enhanced inserts and tungsten carbide inserts protect shirttail for maximum abrasion resistance.

43


#

RockSwift System

Core Barrel Features

Preservation and Stabilization Services

Coring Services

45

Coring technologiesHalliburton offers a full range of coring services from unconsolidated to ultrahard abrasive formations. With proven global performance of over 400 jobs performed each year, we have a 94% core recovery rate. We offer best-in-class core bit technology to maximize ROP and extend bit life.

Our on-site Design at the Customer Interface (DatCISM) process provides custom solutions to maximize core recovery. MaxBHA software analysis is performed for the coring BHA to provide additional information on drilling performance. We provide superior coring service quality to more than 170 customers in 47 countries to meet your coring objectives.

Applications Tendency to Jam from Fractured ReservoirSoft Friable or UnconsolidatedExpensive Rig Time

Horizontal or High AngleHigh Pressure/High Temperature

SolutionsRockStrong Coring System, Full Closure System, MaxBHA RockStrong, RockSwift Coring System, MaxBHARockStrong, MaxBHARockStrong, MaxBHARockStrong, RockSwift, MaxBHA

PDC Core HeadFor Soft Formations

TSP Core HeadFor Medium to

Hard Formations

Diamond Impregnated Core Head

For Hard/Abrasive Formations

Tool Size

Hole SizeCompatibilityCore Barrel SizeCore Size

4-3/4 x 2-5/8 5-1/2 x 3-1/4 6-3/4 x 4

5-7/8 x 7 6 x 8-1/2 8 x 9

4-3/4 5-1/2 6-3/42-5/8 3-1/4 4

RockStrongTM Coring SystemDesigned specifically for high pressure high temperature (HPHT) environments and hard, abrasive rock, the RockStrongTM coring system incorporates best-in-class corehead technology, anti-jamming design, and engineered vibration mitigation.

The RockStrong coring system features a unique swivel assembly, making it the most robust coring tool on the market. To date, it is the only system specifically designed for extreme wellbore environments. It is field proven to deliver high quality core samples in the harshest conditions. The system was built to overcome ultra-deepwater coring issues and high vibration levels encountered in tight multi-layer formations. Anti-Jamming Features Include a top spacer

assembly which acts like a preloaded spring to absorb axial vibrations along the inner assembly

Increased Space-Out Capacity Withstands HPHT conditions

Ultra Stable Double Bearing Assembly Ensures smooth core entry and reduces risk of damage to the core

Pre-Loaded Adjustment System Reduces fatigue effects and extends the vibration level that can be sustained by the core barrel

Coring Services

WLC 02-1-2ECOR 02-1-4D#30 Core Catcher Rev.6

Designed for coring medium hard, hard fractured, or interbed-ded formations. Shown to the right, the spring catcher opens as the core enters. When the core barrel is lifted off the bottom, the spring catcher closes to break off the formation and retain it within the inner tube.

CORING JAMMING

Stand Pipe Pressure Stand Pipe Pressure

COR 02-1-6E & 7DHSB 02-1-1AWLC 02-1-2F

#28 Hydro Seat Barrel

The Hydro-Seat Barrel (HSBTM) system, an optional feature, provides a clear and instantaneous indication on the rig floor if core jamming occurs. The floating, flexible barrel (shown to the right) is hydraulically seated which means much less stress on the core at entry. Jamming lifts the inner barrel restricting mud flow, and increases the pressure reading at the surface.

COR 02-1-5B

#13 Heavy Duty Threads

The Heavy Duty Threadfrom reduces thread damage and costly delays. It adds reliability in horizontal ap-plications and allows longer core barrels for saving trips and valuable rig time. The heavy duty buttress threads are double shouldered and flush internally and exter-nally. They greatly increase tensile strength, flex capac-ity, torsional strength, and fatigue life compared with conventional threads. Its fatigue life is ten times greater than conventional types.

Heavy Duty Threadform (patented)

The Hydro-Seat Barrel (HSBTM) System

Heavy Duty Core Catcher

46

Coring Services

47

RockSwifttM Coring SystemThe RockSwiftTM wireline coring system allows operations to pull the core out of the hole by a wire while the core barrel remains downhole. The inner assembly containing the core is pulled, and as soon as the core is retrieved an empty tube is dropped in and hydraulically kept inside the bore barrel, ready to complete the next core cut.

A drill plug can alternatively replace the removable tube to fill the corehead with a cutting structure in order to drill towards the next core point.

Hole Size Capabilities

Core SizeRecommended Drill String

Drift Diameter

Latch LesTM4-3/4 x 1.713

Latch LesTM Triple Tube6-3/4 x 2.02

RockSwift6-3/4 x 3

5-7/8 - 7 8 - 9 8 - 9

1.713 2.02 3

2-1/4 2-13/16 4-1/8

Poland: Fast Recovery for Accurate Gas-in-Place Measurement

HalliburtonDBS3RockSwiftTM wireline coring system with 8-1/2 x 3 FC3643 PDC core head

Cut820feet(250meters)in29runswithasinglecorehead

100%corerecovery

Right: RockSwiftTM Coring System in the La Luna Shale in Colombia.

RockSwiftTM coring system comes in a variety of tool sizes with different hole size capabilities:

Coring Services

#^10 Full Closure system rev.8Ball Activated Bottom

Core Barrel Features

FCS is ideal for soft, unconsolidated formations. A hydraulic collaps-ing sleeve minimizes mechanical parts and increases reliability.

Full Closure System is a parallel concept of core catcher that allows an efficient recovery of soft to highly unconsolidated cores. The FCS is available as a conversion kit to the Conventional Barrel and con-sists of two main assemblies: the FCS Inner Tube Plug that is assem-bled to the Conventional Swivel and the FCS Collapsing Shoe that is fitted located at the top of the conventional lower half shoe contain-ing the core catcher. An additional Acitvation Sub is finally fitted around the FCS Collapsing Shoe to create a TFA restriction upon request which will bring the latter to collapse around the core foot.

The FCS is hydraulically activated by a drop ball and is fully compat-ible with Halliburton DBS Conventional Coring equipment.

GLI 02-1-2A & 1AWLC -02-1-3A

#35 Glider Interior Icon

The Glider system provides a layer of lubricating non-reactive fluid between the core and inner tube to prevent jamming and protect the

COR 02-1-4C &7CWLC 02-1-3C

#11 Posi Close

The PosiCloseTM system also maximizes core recovery in soft for-mations. Unrestricted entry eliminates jamming from premature catcher/core contact.

The catcher system fully closes to ensure complete retention through-out retrieval.

FCS (Full Closure System)

Glider System

PosiCloseTM System

48

Coring Services

49

#^12 G-ClampTube Alignment DeviceInner tube alignment

device prevents core damage from rotating and flexing of inner tubes, while separating the inner tubes prior to laydown.

Core Gamma Logger (CGL) pro-vides on-site analysis for gamma ray logs. It allows real-time decisions on further coring, testing, or comple-tions by correlating cored sections with anticipated lithology, delineat-ing shale from non-shale sections. The CGL is portable and works verti-cally on the rig floor or horizontally on the catwalk.

Lay-down cradle protects against bending and impact damage. The cradle is equipped with rollers.

CGL 02-1-1A#40 Core Gamma Logger (Large)

COR 02-1-9DHND 02-1-1A, 2A

#12 Laydown Cradle

Preservation and Stabilization Services

COR 02-1-9C#22 Plug Taker

1

23 4

56

0dar

1

23 4

56

0dar

Plug taker cuts core samples to aid on-site operating decisions or to ship them to the laboratory for further anlysis. Operators can also take plugs at the surface to prevent further diffusion, and with trimming provide the labora-tory an inner plug untouched by drill-ing fluids, which prevents alternation.

HND 02-1-3C#34 Saw

Power saw cuts fiberglass or aluminum inner tubes into three foot sections, if requested by the customer. The blade is normally diamond tipped, and the saw pneumatic depending on the rig location. The boxs safety housing offers an open top for access.

#9 Gypsum PreservationCOR 02-1-9EGYP 02-1HND 02-1-3A

Shock Absorbing Rack#32

Gypsum Preservation Service stabilizes the core with a gypsum mixture inside the inner tube to prevent damage during handling and transportation. Gypsum is injected into the space between the tube and core. It does not affect any petrophysical or wettability proper-ties, and it is the best technology available in terms of health, safety, and the enviornment.

Special shipping baskets can be spring-loaded to protect cores during transport. The basket can ship full length cores, the preference of some laboratories.

Coring Services

XR Reamer

nBR near Bit Reamer

uR underReamer

Single Piece Hole opener

Hole Enlargement Tools

51

Hole Enlargement technologies

Halliburtons hole enlargement solutions can help solve your challenges whether you are using a rotary steerable BHA, a steerable motor BHA, or a conventional rotary drilling system. We offer innovative drilling technologies to mitigate drillstring vibration during hole enlargement.

Halliburtons hole enlargement tools operate efficiently, improving circulation, reducing the risk for fracturing formations to overcome your hole enlargement challenges.

ChallengesRotary Steerable BHASteerable Motor BHAConventional Rotary BHA

SolutionsXR, SPHONBR UR,NBR,SPHO,XR

Halliburton DBS offers high performance downhole tools for hole enlargement, torque reduction and drag resistance improvement needs.

Standard arms for soft applications have a single row of PDC cutters on our hole enlargement tools.

Two rows of PDC cutters are used for medium to hard applications.

Three rows of PDC cutters are for hard/abrasive applications; reinforced hardfacing.

The NBR tool features dome PDC cutters which prevent cutters from damaging the casing if pistons are released inadvertently within the casing shoe.

Cutting StructuresNBR Pistons

XR Reamer ArmsWithdedicatedcutterarmsetsforeachholeopeningsize,theXRreamer can increase hole size up to 1.5 times the pilot hole diameter.

The arm hinges are protected by PDC cutters, gauge hardfacing and dome inserts. Drilling loads are broadly distributed across the body and arm geometries so that vibrations are greatly reduced.

Hole Enlargement

The SPHO cutting structure is designed using force and torque balancing technology. There are three cutter options available:

Conventional Tough Extreme

The cutting structure can be customized as needed to fit the application.

Operating Principles

UR Reamer ArmsThe largest in the market in terms of enlargement capability, the tool is specifically designed for gravel packing, coalbed methane and gas storage applications where enlarged hole size is critical for optimizing well production.

For standard applicationsPDC cutters are used.

For medium to hard formationsinterbedded with hard layers, the mixed cutter is comprised of PDC cutters backed up with diamond im-pregnated disks.

For hard/abrasive formationsa fully diamond impregnated cutting structure is used.

Single Piece Hole Opener

Hydraulic force activates the cutter arms on the UnderReamer (URTM Tool). (shown top right). With the pumps off, a return spring closes the arms. There is no locking device. A rack and pinion mechanism transmits the drive rod motion to open the arms, and stop blocks allow for two different arm opening angles, 90 and 35.

The NBR tool operates solely on hydraulic bore pressure (shown bot-tom right). A minimal increase in internal pressure acts on the flanges, breaks the shear pin and forces the pistons to move radially. Return springs close the pistons when flow decreases.

XRReamerisactivatedbyaballdrop.Whentheballseats,apressuredifferential is seen at the shear pin and the arms are activated. This pressure differential can be seen at surface indicating that the tool has moved into the active state. A second ball is then dropped to deacti-vate the arms.

Hole Enlargement

# 29 4A 4B NBR operating principle

8A Under Reamer Operating Principle#29

UR Tool

NBR Tool

XR Reamer

52

53

TheXRTM Reamer is the only tool capable of enlargement up to 1.5 times the pilot hole or drift diameter. The toolprovidesdependableholeenlargementwhileminimizingBHAvibration.TheXRReamerisproveninhighangle extended reach applications where it minimizes downhole vibration resulting in reliable performance, even in challenging environments.

Aself-stabilizedbodyisoneofmanytechnologicalfeaturesembeddedintheXRReamer.BesidesminimizingBHA whirl, the technology produces a quality enlarged wellbore and extends drill string component life.

TheXRReamerautoblockingtechnologyusesthedynamicandfullyautomatedblockingtoassurethearmsareopen at all times while WOB is applied. This mechanism has been chosen because in expandable enlargement applications any physical locking open feature may expose the customer to the risk of losing the entire BHA due to the mechanical locks failure to disengage. This feature provides improved surface quality for the customer.

Reliable Autoblocking SystemAllows the use of optimum WOB while drilling as all the loads are transferred to the reamer body and drillstring rather than on arms and internal parts

Articulated Arm DeploymentFor tool reliability, durability and hole quality

Large Flow Area For efficient cuttings removal

Self-Stabilized BodyMinimizes BHA whirl, making the hole enlargement operation more efficient

Norway: World Record in Reservoir Section

HalliburtonXR800toolwith9arms

Successfulreamingtoatotaldepthof6,363meters(20,876feet)

The4,297meter(14,098feet)longsectionwasopenedin1run

TheXR800setaworldrecordforthelongestexpandableholeenlargementruninareservoir section

XR Reamer Hole Enlargement toolQuality Hole Enlargement While Drilling

Hole Enlargement

The NBR tool has borehole enlargement capabilites up to 1.2 times the pilot hole diameter, when activated. The NBR tool can be used behind the drill bit or further up the BHA in rotary steerable systems. The tool is a concentric expandable reamer which is engineered to run between the downhole motor and above any drill bit.

The NBR tools concentric technology substantially reduces BHA vibration compared to eccentric tools or bi-center bits, improving steerability and stability. The greater stability of the NBR tool helps ensure a gauged oversize hole that can help improve circulation, and overcome swelling and moving formation problems.

Gulf of Mexico: Outstanding Product Performance

HalliburtonNBR800tool

Successfullyenlargedtheentiresectionofthewellinasinglerunwithexcellentdirectionalcontrol

Estimatedcostsavingsof$59,000inrigtimealoneforthecustomer,byeliminatingatriptopick up a second enlargement tool

Shear Pin Prevents tool activation while drilling out shoe track

Back Reaming CuttersAllows rotation out of the hole

nBR (near Bit Reamer) tool

#29 Near Bit Reamer

54

No Locking DevicesTo prevent pistons from inadvertently locking in the open position. Return springs close arms when flow decreases

Solid One Piece BodyStandard API, stress relieved connection

Balanced ConcentricSubstantially reduces BHA vibration compared with eccentric tools or bi-center bits, improving steerability and stability

Hole Enlargement

55

The UR tool is a heavy duty tool for enlarging the borehole up to 2 times the pilot hole diameter. It offers a variety of completion options since it can be selectively activated or deactivated downhole.

The UR tool can enhance production by expanding the hole for gravel packing, scraping filter cake, plus enabling gas storage underground.

Under Reamer#29

Interchangeable NozzlesAllow variable hydraulic schemes

Standard API Stress relieved connection

Hardfacing at the Leading Edge Is part of the robust construction

Interchangeable Nozzles at Arm Level Provide cooling and cleaning of cutter arms

Australia: Successful Under Reaming of 450 meters (1,476 feet) of coal

HalliburtonUR800Tool

Reamingofthe83/4pilotholeto121/4 was successfully conducted to 1100 meters

Rateofpenetrationof40metersperhour

TheUR800successfullyunderreams450 meters (1476 feet) of coal in a Coal Seam Gas well

uRtM (underReamer) tool

Hole Enlargement

1000

800

600

400

200

0

1200

Depth In Depth Out

1100mMD

650mMD

450 meters (1476.38 ft)(Interval Reamed)

Hole Enlargement

56

The Single Piece Hole Opener (SPHO) is an enhanced version of a PDC hole opener. During or after drilling, the SPHO concentrically enlarges the pilot hole. The SPHO features an optimized cutting structure, single piece construction, a self-stabilized body, and interchangeable nozzles. The tool reduces vibration while reaming to preserve the cutting structure, thereby increasing ROP and maintaining steerability. It is milled from a single steel bar and to help ensure proper hardness and structure integrity.

The SPHO cutting structure is designed using our drill bit software for force balance and torque balance. The specialized capability of using the drill bit software to design a downhole tool sets us apart from the competition.

Adjustable Nozzles1 nozzle per blade allows variable hydraulic schemes

Self-Body StabilizationIs integrated with the tool so that no extra stabilization is required when the SPHO is added to the BHA

Single Piece StructureMilled from a single steel bar- the heat cycle is used to make sure the material has proper hardness and structural integrity

Single Piece Hole opener (SPHo)

Optimized Cutting StructureDesigned using force and torque balancing technology

Hole Enlargement

57

CASINGSIZE O.D.IN.

CASINGCOUPLING

O.D.IN.

NORMALWEIGHTLBS/FT.

INSIDE DIAMETER

I.D.IN.

APIDRIFT

I.D.IN.

ROLLER CONEBIT SIZE

O.D.

FIXED CUTTERBIT SIZE

O.D.IN. DEC. IN. DEC.

4-1/2*4.500*

55.000

5-1/25.500

6-5/86.625

77.000

7-5/87.625

8-5/88.625

3.9653.9273.8753.7954.4354.3694.2834.1514.8874.8254.7674.6534.5455.9245.7965.6665.5506.4136.3316.2416.1516.0595.9695.8795.7957.0006.9006.8446.7506.6406.5007.9727.8927.7967.7007.600

3.8753.8753.8753.7504.3754.2504.2504.1254.7504.7504.7504.5004.5005.8754.7504.7504.7506.2506.2506.1256.1256.0005.8755.8754.7506.7506.7506.7506.7506.5006.5007.8757.8756.7506.7506.750

3-7/83-7/83-7/83-3/43-7/83-7/83-7/83-7/84-3/44-3/44-3/43-7/83-7/85-7/84-3/44-3/44-3/46-1/46-1/46-1/86-1/8

65-7/85-7/84-3/46-3/46-3/4 6-3/4 6-3/4 6-1/26-1/27-7/87-7/86-3/46-3/46-3/4

4.0904.0524.0003.9204.5604.4944.4084.2765.0124.9504.8924.7784.6706.0495.9215.7915.6756.5386.4566.3666.2766.1846.0946.0045.9207.1257.0256.9696.8756.7656.6258.0978.0177.9217.8257.725

9.5010.5011.6013.5011.5013.0015.0018.0014.0015.50170020.0023.0020.0024.0028.0032.0017.0020.0023.0026.0029.0032.0035.0038.0020.0024.0026.4029.7033.7039.0024.0038.0032.0036.0040.00

5.0005.0005.0005.0005.5635.5635.5635.5636.0506.0506.0506.0506.0507.3907.3907.3907.3907.6567.6567.656 7.656 7.656 7.656 7.656 7.6568.5008.5008.5008.5008.5008.5009.6259.625 9.625 9.625 9.625

3-7/83-7/83-7/83-3/43-7/83-7/83-7/83-7/84-3/44-3/44-3/43-7/83-7/85-7/84-3/44-3/44-3/46-1/46-1/46-1/86-1/8

65-7/85-7/84-3/46-3/46-3/46-3/4 6-3/4 6-1/26-1/27-7/87-7/86-3/46-3/46-3/4

3.8753.8753.8753.7504.3754.2504.2504.1254.7504.7504.7504.5004.5005.8754.7504.7504.7506.2506.2506.1256.1256.0005.8755.8754.7506.7506.7506.7506.7506.5006.5007.8757.8756.7506.7506.750

API CASING DIMENSIONS

NOTE: Above information for API casing data, refer to Toolpushers Manual or specific manufacturers specifications.* Roller Cone bits are not currently available for this casing size

Resources

58

CASINGSIZE O.D.IN.

CASINGCOUPLING

O.D.IN.

NORMALWEIGHTLBS/FT.

INSIDE DIAMETER

I.D.IN.

APIDRIFT

I.D.IN.

ROLLER CONEBIT SIZE

O.D.

FIXED CUTTERBIT SIZE

O.D.IN. DEC. IN. DEC.

9-5/89.625

10-3/410.750

11-3/411.750

13-3/813.375

1616.000

18-5/818.625

2020.000

7.5007.3868.9078.8458.7658.6798.5998.5258.379

10.0369.9849.7949.6949.6049.5049.404

10.92810.84410.72410.61612.55912.45912.35912.25912.19115.06214.93614.82217.567

-18.93618.81218.54218.188

6.7506.7508.7508.7508.7508.5008.5008.5008.3759.8759.8759.5009.5009.5009.5007.750

10.62510.62510.6259.875

12.25012.25012.25012.25011.00014.75014.75014.75017.500

-17.50017.50017.50017.500

6-3/46-3/48-3/48-3/4 8-3/4 8-1/28-1/2 8-1/2 8-3/89-7/89-7/89-1/29-1/29-1/29-1/28-3/4

10-5/810-5/810-5/89-7/8

12-1/412-1/412-1/412-1/4

1114-3/414-3/414-3/417-1/2

-17-1/217-1/217-1/217-1/2

7.6257.5119.0639.0018.9218.8358.7558.6818.535

10.19210.0509.9509.8509.7609.6609.560

11.08411.00010.88010.77212.71512.61512.51512.41512.34715.25015.12415.01517.755

-19.12419.00018.73018.376

44.0049.0029.3032.3036.0040.0043.5047.0053.5032.7540.5045.5051.0055.5060.7065.7042.0047.0054.0060.0048.0054.5061.0068.0072.0065.0075.0084.0087.50

-94.00

106.50133.00169.00

9.6259.625

10.62510.625 10.625 10.625 10.625 10.625 10.62511.75011.750 11.750 11.750 11.750 11.750 11.75012.75012.75012.75012.75014.37514.37514.37514.37514.37517.00017.00017.00020.000

-21.00021.00021.00021.000

6-3/46-3/48-3/48-3/4 8-3/4 8-1/28-1/2 8-1/2 8-3/89-7/89-7/89-1/29-1/29-1/29-1/28-3/4

10-5/810-5/810-5/89-7/8

12-1/412-1/412-1/412-1/4

1114-3/414-3/414-3/417-1/2

-17-1/217-1/217-1/217-1/2

6.7506.7508.7508.7508.7508.5008.5008.5008.3759.8759.8759.5009.5009.5009.5007.750

10.62510.62510.6259.875

12.25012.25012.25012.25011.00014.75014.75014.75017.500

-17.50017.50017.50017.500

API CASING DIMENSIONS

NOTE: Above information for API casing data, refer to Toolpushers Manual or specific manufacturers specifications.* Roller Cone bits are not currently available for this casing size

Resources

Recommended Make-up torque

TORQUE2-3/8 (API Reg.)

2-7/8 (API Reg.)

3-1/2 (API Reg.)

4-1/2 (API Reg.)

4-1/2 (I.F. Box)

6-5/8 (API Reg.)

6-5/8 (API Reg.)

7-5/8 (API Reg.)

7-5/8 (API Reg.)

8-5/8 (API Reg.)

1

1-1/4

1-1/2

2-1/4

2-1/4

2-13/16

3

3-1/4

3-1/2

3-1/2

33-1/83-1/43-1/23-3/43-7/84-1/84-1/44-1/25-1/25-3/4

66-1/46-1/2

78

7-1/27-3/4

88-1/47-1/27-3/4

88-1/48-1/28-3/4

99-1/49-1/28-1/28-3/4

99-1/49-1/29-3/4

1010-1/410-1/2

1,793*2,422*3,069*3,071*4,6204,6625,173*6,309*7,665

12,461*16,488*17,56017,76623,743*30,94132,16937,119*42,76943,14743,52537,119*40,75341,11441,47448,321*57,73567,38667,90868,43148,321*57,735*63,82464,31864,81397,22998,01298,72599,437

RECOMMENDED MAKE-UP TORQUE - FIXED CUTTER BITS

CONNECTION MAX. PIN I.D. BIT SUB O.D. MIN. MAKE-UPIN.IN.IN.

RECOMMENED MAKE-UP TORQUE - ROllER CONE BITS*BIT SIZE

IN. IN. FT./LBSTOOL-JOINT TYPE RECOMMENDED TORQUE

JOULES4-3/45-7/8 to 7-3/87-5/8 to 8-3/49-1/2 to 13-3/414-3/4 to 28

2-7/83-1/24-1/26-5/87-5/8

4500/55007000/9000

12000/1600028000/3200034000/40000

6102/74589492/12204

16272/2169637968/4339246104/54240

NOTE: The tool joint type for the 14-3/4 to 17-1/2 inch rock bit range is either 6-5/8 or 7-5/8 inches per API Reg. *Calculations based on recommendations from API and tool joint manufacturers.

59

Resources

References

60

BIT SIZE (IN)

O.D. TOLERANCE (IN)

API STANDARD FIXED CUTTER BIT TOlERANCES

6-3/4 and smaller6-25/32 to 99-1/32 to 13-3/413-25/32 to 17-1/217-17/32 and larger

-0.015 to +0.00-0.020 to +0.00-0.030 to +0.00-0.045 to +0.00-0.063 to +0.00

aPi tolerances and tFa Values

BIT SIZE (IN)

O.D. TOLERANCE (IN)

API STANDARD ROllER CONE BIT TOlERANCES

6-3/4 and smaller6-25/32 to 99-1/32 to 13-3/413-25/32 to 17-1/217-17/32 and larger

-0.0 to +1/32-0.0 to +1/32-0.0 to +1/32-0.0 to +1/16-0.0 to +3/32

NOZZLE SIZETFA VAlUES OF COMMON NOZZlE SIZES

NUMBER OF NOZZLES7

0.26320.34370.43490.53690.64960.77310.90721.05231.20801.37441.55161.73951.93822.14762.36772.59863.09253.294

4.2092

IN.7/328/329/32

10/3211/3212/3213/3214/3215/3216/3217/3218/3219/3220/3221/3222/3224/3226/3228/32

50.18800.24550.31050.38350.46400.55220.64800.75150.86300.98171.10831.24251.38451.53401.69121.85602.20892.59243.0066

60.22560.29460.37280.46020.55680.66270.77760.90201.03541.17811.33001.49101.66141.84082.02952.22722.65073.11093.6079

40.15041.19640.24840.30680.37120.44180.51840.60120.69040.78540.88660.99401.10761.22721.35301.48481.76712.07392.4053

30.11280.14730.18630.23010.27840.33120.38880.45090.51780.58890.66500.74550.83070.92041.10151.11361.32541.55551.8040

20.07520.09820.12420.15340.18560.22080.25920.30060.34520.39260.44330.49700.55380.61360.67640.74240.88361.03701.2026

10.03760.04910.06210.07670.09280.11040.12960.15030.17260.19630.22170.24850.27690.30680.33820.37120.44180.51850.6013

80.30070.39270.49700.61360.74240.88361.03701.20261.38061.57081.77331.98802.21512.45442.70592.96983.53434.14794.8106

90.33820.44180.55910.69030.83530.99401.16661.35301.55321.76711.99492.23652.49202.76123.04423.34103.97614.66645.4119

100.37580.49090.62130.76700.92811.10451.29621.50331.72571.96352.21662.48502.76883.06803.38243.71224.41795.18496.0132

References

61

CUTTING STRUCTUREBEARINGS/

SEALS GAUGEOTHER DULL

CHAR.REASON PULLED

INNER ROWS

OUTERROWS

DULL CHAR. LOCATION

1 2 3 4 6 7 8

INNER CUTTING STRUCTURE

OUTER CUTTING STRUCTURE

DULL CHARACTERISTICS

LOCATION

BEARINGS/SEALS

A measure of lost, worn, and/or broken cutting structure.Linear Scale: 0-8 0 - No lost, worn and/or broken cutting structure 8 - All of cutting structure lost, worn and/or broken

BF - Bond FailureBT - Broken CuttersBU - Balled UpCR - CoredCT - Chipped CuttersDL - Delaminated CuttersER - Erosion HC - Heat Checking JD - Junk DamageLM - Lost Matrix LN - Lost Nozzle LT - Lost Cutters NO - No Dull Characteristics NR - Not Rerunnable PN - Plugged Nozzle/Flow Passage RO - Ring OutRR - RerunnableWO - Washed OutWT - Worn Cutters

C - ConeS - ShoulderN - NoseG - GaugeT - TaperA - All Areas

N/AInner Area2/3 Radius

Outer Area1/3 Radius

X

GAUGE

OTHER DULL CHARACTERISTICS

REASON PULLED OR RUN TERMINATED

No Wear Worn Cutter

Lost Cutter(LT)

Delaminated

Halliburtons fixed cutter bits are tip ground to exacting tolerances at gauge O.D. per API spec 7. Depend-ing on the specific design and application, as much as .080 of an inch of the cutter diameter may be ground flat. This can be mistaken for gauge wear if unfamiliar with our produts. Please ensure that the dull bits are in gauge with a calibrated No Go ring gauge.

I - In Gauge1 - 1/16 Out of Gauge2 - 1/8 Out of Gauge4 - 1/4 Out of Gauge

(Refer to column 3 codes)

BHA - Change Bottom Hole Assembly CM - Condition MudCP - Core PointDMF - Downhole Motor FailureDP - Drill PlugDSF - Drill String FailureDST - Drill Stem TestDTF - Down Hole Tool FailureFM - Formation Change HP - Hole Problems HR - Hours on BitLH - Left in HoleLOG - Run LogsPP - Pump PressurePR - Penetration RateRIG - Rig RepairTD - Total Depth/Casing DepthTQ - TorqueTW - Twist OffWC - Weather ConditionsWO - Washout in Drill StringGauge

Shoulder

Taper

Nose

1

2

3

4

5

6

7

8

iaDC Dull grading

References

62

iaDC Dull grading

INNER CUTTING STRUCTURE

OUTER CUTTING STRUCTURE(Gauge row only)In columns 1 and 2, a linear scale from 0 to 8 is used to describe the condition of the cutting structure according to the following:

Steel Tooth BitsA measure of lost tooth height due to abrasion and/or damage.0 - No loss of tooth height8 - Total loss of tooth height

Insert BitsA measure of total cutting structure re-duction due to lost, worn and/or broken inserts.0 - No lost, worn and/or broken inserts8 - All inserts lost, worn and/or broken

All inner rows

BEARINGS/SEALSNon-Sealed BearingsA linear scale estimating bearing life used.0 - No life used8 - All life used, i.e. no bearing life remaining

Sealed BearingsE - Seals EffectiveF - Seals FailedN - Not Able To Grade

CUTTING STRUCTUREBEARINGS/

SEALS GAUGEOTHER DULL

CHAR.REASON PULLED

INNER ROWS

OUTERROWS

DULL CHAR. LOCATION

1 2 3 4 6 7 8X

DULL CHARACTERISTICS(Use only cutting structure related codes)BC - Broken Cone*BT - Broken TeethBU - Balled UpCC - Cracked Cone*CD - Cone Dragged*CI - Cone InterferenceCR - CoredCT - Chipped TeethER - ErosionFC - Flat Crested WearHC - Heat CheckingJD - Junk DamageLC - Lost Cone*LN - Lost NozzleLT - Lost TeethNO - No Dull CharacteristicNR - Not RerunnableOC - Off Center WearPB - Pinched BitPN - Plugged Nozzle/Flow PassageRG - Rounded GaugeRO - Ring OutRR - RerunnableSD - Shirttail DamageSS - Self-Sharpening WearTR - TrackingWO - Washed Out BitWT - Worn Teeth

LOCATIONC - ConeS - ShoulderN - NoseG - GaugeT - TaperA - All Areas

GAUGE(Measure in fractions of an inch)I - In Gauge1 - 1/16 Out of Gauge2 - 1/8 Out of Gauge4 - 1/4 Out of Gauge

OTHER DULL CHARACTERISTICS(Refer to Column 3 codes)

REASON PULLED OR RUN TERMINATEDBHA - Change Bottom Hole AssemblyCM - Condition MudCP - Core PointDMF - Downhole Motor FailureDP - Drill PlugDSF - Drill String Failure DST - Drill Stem TestDTF - Downhole Tool FailureFM - Formation ChangeHP - Hole ProblemsHR - Hours on BitLIH - Left In HoleLOG - Run LogsPP - Pump PressurePR - Penetration RateRIG - Rig RepairTD - Total Depth/Casing DepthTQ - TorqueTW - Twist OffWC - Weather ConditionsWO - Washout in Drill String

* Show cone # or #s under location 4. Cone numbers are identified as follows: - The number one cone contains the center most cutting element. - Cones two and three follow in a clockwise orientation as viewed looking down at the cutting structure with the bit sitting on the pin.

Cutting Structure Wear

1

2

3

4

5

6

7

8

References

63

Dull Three Cone BitsObtain a nominal size ring gauge. A nominal ring gauge is one that is exact in size. For example, a 12-1/4-in. ring gauge is 12-1/4-in. exactly.Rotate all cones so that one of the gauge teeth on each cone is at the maximum gauge point*. (Remember, soft formation bits with large offsets have the mximum gauge points on each cone located towards the leading side of the cone).Place the ring gauge over the bit and locate it at the maximum gauge point.Pull the ring gauge tight against the gauge points of two cones as shown.Measure the gap between the third cones gauge point and the ring gauge**.Multiply this measurement by 2/3 for accuracy. This result is the amount the bit is under gauge. In the illustration, for example, measurement shows 3/8-in., while the bit is actually 1/4-in. out of gauge.Report this amount to the nearest 1/16th of an inch.

Sharp BitsWhen ring gauging a sharp (new) roller cone bit, a nominal ring gauge may not fit over the cones due to the plus tolerances. Obtain the appropriate Go and No Go gauges for each bit size.The Go gauge is manufactured to the maximum roller cone bit tolerance (see API Standard Roller Cone Rock Bit Tolerances) plus its own tolerance +.003 to -0 inches for clearance.The No Go gauge is manufactured to the minimum roller cone bit tolerance, which is nominal bit diameter, plus its own tolerance +0- to -.003-in.

*

**

HA

L908

7

*

11

2

3

45

6

7

1

2

3

Roller Cone Ring gauging

References

References

64

NORTH AMERICAUNITED STATESTheWoodlands,TXTEL: +1-936-442-4700

Houston,TXTEL: +1-281-871-6170

Midland,TXTE: +1-432-682-43

Documents

DBS_V2 Halliburton