(-- Application Guide

(-- Product Nomenclature

(-- API Diamond Bit Tolerance

(-- TFA Values

(-- API Connection Chart

(-- Operating Guidelines For PDC Bits

(-- PDC Application Check List

(-- Recommended Make-Up Torque

Table of Contents

Bit Selection & Application

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Hughes Christensen Electronic Catalog.

Diamond Drill Bits

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Diamond Product Applications

Diamond Product ApplicationsBit Applications ABD BD BDH BDS BDP BX STR AG G S RWD SRWD STRWD

ConventionalMultipurposeHard AbrasiveSoft AbrasivePlastic ShalesSteerableSlimholeVibration ControlBallingHard RockTurbineHole Enlargement – RotaryHole Enlargement – SteerableHole Enlargement – Slimhole

Diamond Product Nomenclature

ABD, BD (Black Diamond) Series Diamond Compact BitsBlack Diamond is a premium line of multi-purpose bits,custom designed for specific applications. Utilizing“Application Engineered Cutters” and “EngineeredCutter Layouts”, Black Diamond bits can be tailored tomeet the unique requirements of specific formationsand operating parameters. Designs also utilize newhydraulics, gauge design and streamlined geometry.

BX (Black Trax) Series Diamond Compact BitsBlackTrax is a revolutionary line of PDC bits designedspecifically for steerable applications. BlackTrax bitsfeature a long tandem gauge. This less aggressivegauge with limited side cutting action, has improvedsteerability and delivers a quality wellbore. BlackTraxbits take advantage of Engineered Cutter Technology.Each bit’s cutter configuration is tailored for a specificapplication. Like BD bits, BX bits incorporate newhydraulics, gauge design and streamlined geometry.

AG/G (Gold) Series Diamond Compact BitsDesigned for conventional drilling, the AG/G bits fea-ture Stress Engineered Cutters, Engineered CutterPlacement, Carbide Supported Edge, and Black Icepolished Cutters. AG Series bits incorporate Anti-Whirltechnology to extend their life and application range.

STR (STAR) Series Diamond Compact BitsThis is a premium line of small diameter PDC bits.Gold Series features like Stress Engineered Cutters,Carbide Supported Edge geometry and Black Ice pol-ished cutters make these the right choice for the chal-lenges of slim hole and directional applications.Where steerability is a concern, STAR bits are avail-able with increased cutter back rake, and wearknotsto limit torque variability.

S-Series BallaSet BitsS series bits utilize thermally-stable polycrystallinediamond cutters to drill medium to hard formations, ordiamond impregnated segments to drill hard, abrasiveformations.

D-Series Natural Diamond BitsThe D Series bits are surface set with natural dia-monds of various grades and concentrations to drill avariety of harder, more abrasive formations.

Diamond Drill Bit SeriesPDC* BallaSet Natural Diamond BallaSet/Natural Diamond

Spectrum TechnologyBlack Diamond BDAnti-Whirl Black Diamond ABDBlackTrax BXAuto Trak** TX**

Conventional PDCGold Series GAnti-Whirl Gold Series AG

Impregnated PDCBallaSet S

Natural Diamond D, TSD Combination SD

*PDC Cutter Size is identified by the first digit of the bit nomenclature3 = 3/8” cutter 4 = 1/2” cutter 5 = 3/4” cutter i.e. BD554 has 3/4” cutters

**Designed for use in conjunction with Baker Hughes INTEQ’s AutoTrak Rotary Steerable Tool

Technical Data

TFA VALUES OF COMMON NOZZLE SIZES

NUMBER OF NOZZLES1 2 3 4 5 6 7 8 9 10

7 .0376 .0752 .1127 .1503 .1877 .2255 .2631 .3007 .3382 .37588 .0491 .0982 .1473 .1963 .2454 .2945 .3435 .3927 .4418 .49099 .0621 .1242 .1864 .2485 .3106 .3728 .4249 .4970 .5591 .6213

10 .0767 .1534 .2301 .3060 .3835 .4602 .5369 .6136 .6903 .767011 .0928 .1856 .2784 .3712 .4640 .5568 .6496 .7424 .8353 .928112 .1104 .2209 .3313 .4418 .5522 .6627 .7731 .8836 .9940 1.104513 .1296 .2592 .3889 .5185 .6481 .7777 .9073 1.0370 1.1666 1.296214 .1503 .3007 .4510 .6013 .7517 .9020 1.0523 1.2026 1.3530 1.503315 .1726 .3451 .5177 .6903 .8629 1.0354 1.2080 1.3806 1.5532 1.725816 .1963 .3927 .5890 .7854 .9817 1.1781 1.3744 1.5708 1.7671 1.963418 .2485 .4970 .7455 .9940 1.2425 1.4910 1.7395 1.9880 2.2365 2.485020 .3068 .6136 .9204 1.2272 1.5340 1.8408 2.1476 2.4544 2.7612 3.068022 .3712 .7424 1.1137 1.4849 1.8561 2.2273 2.5986 2.9698 3.3410 3.7122

NOZZLE SIZE IN 32nds

API DIAMOND BIT TOLERANCESNOMINAL BIT SIZE O.D. O.D. TOLERANCE

inches inches mm*

up to 6 3/4, incl. +0. - 0.015 +0 - 0.386 25/32 to 9, incl. +0. - 0.020 +0. - 0.51

91/32 to 13 3 /4, incl. +0. - 0.030 +0. - 0.761325/32 and larger +0. - 0.045 +0. - 1.14

*Converted from inches

API CONNECTION CHART

BIT O.D. RANGE API REG. RECOMMENDED MAKE-UP BIT SUB SHANK SIZEPIN CONN TORQUE RANGE O.D. O.D. I.D.

inches inches kNm* 1000 ft-lbs inches inches inches

2.4 - 2.7 1.8 - 2.0 34 - 41/2 23/8 3.3 - 3.7 2.4 - 2.7 31/8 31/8 1

4.2 - 4.6 3.1 - 3.4 31/4

4.2 - 4.6 3.1 - 3.4 31/245/8 - 43/4 27/8 41/8 11/4

6.2 - 6.9 4.6 - 5.1 33/4 & larger

7.1 - 7.7 5.2 - 5.7 41/855/8 - 63/4 31/2 8.5 - 9.4 6.3 - 6.9 41/4 43/4 11/2

10.4 - 11.4 7.7 - 8.4 41/2 & larger

73/8 - 77/8 16.9 - 18.6 12.5 - 13.7 51/2 53/4 13/441/2 22.4 - 24.5 16.5 - 18.1 53/4

83/8 - 9 23.9 - 26.3 17.6 - 19.4 6 & larger 63/4 13/4

50.3 - 55.3 37.1 - 40.8 71/295/8 - 121/4 65/8 8 3

51.5 - 56.7 38.0 - 41.8 73/4 & larger

65.5 - 72.0 48.3 - 53.1 81/2 93/4 3143/4 - 171/2 75/8 78.2 - 86.1 57.7 - 63.5 83/4

81.3 - 89.5 60.0 - 66.0 9 & larger 111/2 3

*Converted from ft - lbs NOZZLE SIZE IN 32nds

Operating Guidelines for PDC Bits

General InformationUnder the right combination of formation and operat-ing conditions, all bits are subject to whirl and relatedcutter impact damage. HCC anti-whirl bits aredesigned to provide a much wider range of operatingparameters and conditions under which the bit will not whirl.

To take advantage of the unique features of thesebits, it is necessary that the bits be run properly. Ingeneral, slower rotary speeds and higher weightsthan “typically” applied to PDC bits are preferred as ameans of producing the desired penetration rates. Itis also important that the proper procedures be fol-lowed starting the bit and when making connections.Following these procedures will assure maximum bitlife and ROP.

Pre-Run Preparation:

Proper inspection of the previous bit is important todetermine hole gauge conditions and if there are anypieces missing from the bit that could cause damageduring the next run.

Stabilization has proven effective in maintainingstraight hole and maximizing bit performance and isrecommended for all PDC bit applications. However,local experience or hole conditions may not requirethat stabilization be run. All stabilizers and rollerreamers should be ring-gauged to be sure that theyare not oversized.

Operating Guidelines

Rotary Applications:1.With the bit just off bottom, bring the pumps up to

full flow and start the rotary table at 30-60 rpm.2.Drill the first few feet at the start-up weight-on-bit to

establish the new bottomhole pattern. Tables aresupplied with the correct start-up WOB for each bitsize and style. The start-up parameters should beused for at least the length of the bit.

3.After the bit has formed its own bottomhole pattern,increase the weight on bit smoothly and evenly tothe normal drilling weight on bit. In very soft forma-tions this may be very close to the start-up WOB.Harder formations will take longer to break-in andeventually require higher operating weights. Optimal WOB is that point at which additionalweight does not increase the penetration rate or the torque limit is reached.

4.The rotary speed can now be increased to thedesired level. The optimal rotary speed is that pointat which additional rpm does not increase the rateof penetration or the torque limit is reached. Softerformations will generally be more responsive toincreases in rpm. In harder and more abrasive for-mations high rotary speeds can cause the cutters to wear prematurely. It is important to monitor therop vs. rpm to ensure that lowest rpm is used forthe desired penetration rate. Generally, the recommended operating range is 60-240 rpm.

5.Continual monitoring and adjusting of operationalparameters as lithology changes are encounteredwill maximize bit life and penetration rates.

Making a Connection:Making a connection follows a similar procedure tostarting up but without the break-in period.1.At the end of the Kelly, lower the rotary to 30-60

rpm.2.Clamp the brake and allow for a portion of the

weight-on-bit to drill-off for several minutes.3.Stop the rotary as the bit is lifted off bottom.4.After making the connection, wash back to bottom

at full circulation. Start the rotary at 30-60 rpm.5.First increase the weight on bit and secondly the

rotary speed as indicated in the prior section.

Downhole Motor and Directional Applications:It is recognized that control of the rpm range of the bitis limited in applications that use downhole motors. Ingeneral, the harder the formation, the lower the rpmshould be. Therefore, it is important to know the application range the bit is required to drill and usethe appropriate downhole motor configuration. AR-Series bits extend PDC applications into harderformations and are recommended to be run on hightorque/low speed motors. Current information sug-gests that in directional applications, AR-Series bitsmay build angle slightly slower than a conventionalPDC bit. Therefore, insure that there is sufficient room in the directional plan to adjust for a slightlyslower build rate. Local experience will dictate theamount of adjustment. Reference SPE paper #24614documenting directional field testing of anti-whirl bits.1.Lower the bit bottom with half the normal drilling

flow rate. Simultaneously bring up the weight andpump speed as drilling is initiated. If the bit is start-ed in a very soft formation where bit balling is apossibility, full flow is recommended. The softnessof the formation will probably cause little or no damage to the cutters and sufficient depth of cut will result in stable drilling in short order.

2.When a directional assembly is being utilized in the rotary mode, keep the drill pipe speed slow (20-40 rpm).

Signs of Bit Whirl

During the run:1.Low penetration rates (<12 ft./hr.) at high rotation

speed (>120 RPM).2.Non-linear ROP response to changes in RPM.3.Drill string vibration.

What to do if you suspect a bit is whirling:1.Slow the rotary speed to 30-60 RPM.2.Increase weight-on-bit until ROP is 12 ft./hr. or

more. (Do not exceed maximum recommendedWOB.)

3.Incrementally increase RPM and plot RPM vs. ROP(curve should be linear if the bit and drill string arenot whirling.)

PDC Bit Application Check List

Formation Considerations* PDC bits are sensitive to changes in lithology.

Optimum parameters are formation dependent andchange with formations drilled.

* PDC bits are mostly used in soft to medium forma-tions where a large amount of cuttings is generated.Hydraulic energy is required to clean and cool the bitand is one of the most important factors affecting ROP.

* PDC cutter wear is accelerated with high RPMs and high WOB when drilling hard and abrasivestringers. For extended bit life, use of low RPMs(approximately 80-120) and lowest possible WOB isrecommended.

Bit Preparation* Check prior bit run for broken teeth or inserts. If

necessary, a junk basket run should be made. Junkin the hole results in early damage of the PDC bit.(Use of a junk basket on bit run prior to the PDC bitrun is recommended.)

* Remove PDC bit from box using a board or boardmat placed under bit to avoid damage. Do not roll biton steel, cement or similar surface.

* Inspect PDC bit prior to going in the hole to ensurethere are no obstructions or foreign matter in it.

* Gauge nozzles before RIH.

* Prepare thread connection with dope and torque to API recommendations. A bit breaker should beused for make-up torque.

Tripping in the Hole* Caution should be taken when passing through the

BOPs, casing shoes and liner hangers.

* Slowly approach known tight intervals and sectionsof high dog leg severity and proceed carefully.

* Avoid reaming with compact bits. Short sectionscan be reamed with very light WOB (approximately2-4 Klbs), maximum flowrate and moderate rotaryspeed.

* Wash down last single/stand slowly with maximumflow rate.

* Tag bottom with pumps on. Circulate approximately6”-12” off bottom for several minutes. If any fill isknown to be on bottom, circulation should be consid-erably longer, while working pipe.

Float Equipment* Float equipment must be PDC compatible if drilled.

* WOB & RPM should be kept as low as possible andyet sufficiently high to drill the equipment (approxi-mately: RPM=80, WOB=6Klbs.).

* Allow WOB to drill off prior to applying additionalweight.

* Keep flow rate at full volume to prevent damage tocutters with high uneven loading.

Bit Break-In* Before bit break-in, compare expected hydraulic

calculations with actual hydraulic readings to detectplugged nozzles, blown nozzles or pump problemsbefore bit is on bottom.

* Soft formations: Bit break-in should be with maxi-mum flow rate (approximately RPM=100, WOB=2-4Klbs.). After 3-4 feet have been drilled, optimizeparameters to begin to maximize ROP.

* Firmer formations: More time should be spentestablishing bottom hole pattern. RPM should bekept near 80-120 and WOB should be increased inincrements of 2 Klbs until drill-off begins. After 2-3feet of hole is drilled in this manner, increase operat-ing parameters to achieve optimum ROP.

* Hand and abrasive stringers:Low RPMs (approximately 80-120) and lowest pos-sible WOB should be used.

Drilling, Connections, Tripping Out of Hole* Drill off before picking up off bottom for next sin-

gle/stand. This practice is useful to reduce thermalshocks of the PDC cutters, especially when drillingfirmer formations.

* After making connections, return to full flow ratewhile WOB and RPM should be increased gradually.

* When tripping out of the hole, slow down throughknown tight spots to avoid gauge damage. Be awarethat PDC bits are full gauge and could readily swaba well if pulled too fast. Again, slow down throughcasing shoe, liner hangers and BOPs to avoid bitdamage.

* PDC bit should be set on a board or board mat.Never stand bit back on steel drill floor.

Recommended Make-up Torque

Diamond Drill Bit Recommended Make-up TorqueAPI Reg. Pin Conn. Recommended Make-up Torque Range Bit O.D.

inches kNm* 1000 ft-lbs inches

2.4 – 2.7 1.8 – 2.0 323/8 3.3 – 3.7 2.4 – 2.7 31/8

4.2 – 4.6 3.1 – 3.4 31/4

27/8 4.2 – 4.6 3.1 – 3.4 31/26.2 – 6.9 4.6 – 5.1 33/4 & larger

7.1 – 7.7 5.2 – 5.8 41/831/2 8.5 – 9.4 6.4 – 7.1 41/4

10.4 – 11.4 7.7 – 8.6 41/2 & larger

16.9 – 18.6 12.5 – 13.7 51/241/2 22.4 – 24.5 16.5 – 18.1 53/4

23.9 – 26.3 17.6 – 19.4 6 & larger

65/8 50.3 – 55.3 37.1 – 40.8 71/251.5 – 56.7 38.0 – 41.8 73/4 & larger

65.5 – 72.0 48.3 – 53.1 81/275/8 78.2 – 86.1 57.7 – 63.5 83/4

81.3 – 89.5 60.0 – 66.0 9 & larger

85/8 92.2 – 95.9 125.0 – 130.0 12