· Quality Management System (QMS) that complies with ISO 9001 requirements. Besides, Volgaburmash QMS has been certified according to API Spec.Q1 for more than 15 years. The Company

PRODUCTCATALOGUEFOR COnsTRUCTiOn inDUsTRY

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www.vbm.ru© Volgaburmash, JSC© Uralburmash, JSC

7 63 25 1605

vbm.ru

Contents

About Company _________________________________________________________________ 2

Innovations _________________________________________________________________________ 8

Quality Management System ____________________________________________ 14

Products for Construction industry ___________________________________20

TechnoPro _____________________________________________________________________________22

FastDrillConstruction __________________________________________________________________28

WaterDrill ______________________________________________________________________________30

DTH ____________________________________________________________________________________32

Sections kits ___________________________________________________________________________34

Support Information __________________________________________________________36

Site ____________________________________________________________________________________48

Contacts ____________________________________________________________________________48

www.vbm.ru www.vbm.ru

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Product Catalogue for Construction Industry Product Catalogue for Construction Industry

About CompAny

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« oVER 1.5 tHouSAnD DRILL bIt DESIGnS »

About Company

Currently, production facilities are equipped with the most advanced multi-axis machining centers, furnaces, heat-treatment machines, welding and hardfacing units purchased from the world’s leading producers.

State of the art equipment enables us to master new bit designs in the shortest time and provides products quality conformance with the international standards.

All products undergo quality control at each manufacturing stage. Since 1997, Volgaburmash, JSC has implemented certified Quality Management System according to ISO standards and API Q1 specification.

Besides, Volgaburmash, JSC and Uralburmash, JSC manufacture components for rock-cutting tools production: forgings and sections of roller cone bits, bodies of PDC bits, tungsten carbide inserts. The Companies carry out continuous technical modernization of production.

Volgaburmash, JSC and Uralburmash, JSC are largest Russian manufacturers of advanced high quality rock-cutting tools for oil&gas, mining and construction industries.

The Companies manufacture over 1000 roller cone bit designs for oil and gas industry ranging from 75.0 mm (2-61/64”) to 660.4 mm (26”) with milled teeth and tungsten carbide inserts; over 250 standard sizes of mining roller cone bits ranging from 75.0 mm (2-61/64”) to 393.7 mm (15-½”) for compressed-air drilling in various mining and geological conditions. Also, Volgaburmash, JSC manufactures over 350 designs of PDC bits with matrix or steel bodies for various drilling applications ranging from 83 mm (3-1/4”) to 444.5 mm (17-1/2”), PDC core bits for core drilling and near-bit stabilizers.

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« oVER 20 mILLIon DRILL bItS HAVE bEEn mAnuFACtuRED »

Rock-cutting tools produced by Volgaburmash, JSC and Uralburmash, JSC are used in the main Russian fields and open casts and in more than 40 other countries. Our background of experience, high scientific engineering potential and the team of professionals give us an excellent opportunity of creating an individual approach to each customer and developing unique drill bit designs for any drilling applications in the shortest time possible.

Since their foundation, Volgaburmash, JSC and Uralburmash, JSC have produced more than 20 million drill bits for oil and gas and mining industries. Due to the products quality and the sales volume the Companies are among the world’s leading rock-cutting tools manufacturers.

Volgaburmash, JSC has also implemented and certified Environment Management System and Health and Safety Management System according to ISO 14001:2004 and OHSAS 18001:2007 requirements.

Since the Companies were founded, their specialists have developed over 2000 drill bit designs. Many of these design solutions are of international novelty. Their authors and the Companies have obtained more than 300 inventor’s certificates and patents for inventions in Russia and 17 other countries. Over fifteen hundred innovations have been put into production.

About Company

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InnoVAtIonS

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The base of the Companies’ development is working out and introducing innovation technologies in all aspects of their activities providing high product quality level: in design engineering, manufacturing technology and after-sales service.

The Companies have worked out a successful thorough system of automated design engineering, technology process planning and engineering evaluation (CAD/CAM/CAE-system) based on the unified environment of Siemens UG NX software system that is widely used by the world’s leading companies.

Innovations

This enables us to shorten lead time for new bit designs, improve their efficiency and reliability due to optimizing design and technology parameters at the design stage, as well as provide an opportunity for creating drill bits for specific applications taking into account technological environment and lithology.

Design engineering system incorporates patented research results, math model simulation, selecting the optimal drill bit design parameters and multi-factor analysis of bit test results.

When designing a bit, a designer has at his disposal software for automated drafting of a profile and bottom-hole coverage, for evaluation of dulling characteristics, selection of optimal parameters of bit hydraulics, load balancing to improve bit steerability as well as analysis of field test results using advanced statistical processing methods.

« IntRoDuCInG InnoVAtIon tECHnoLoGIES In ALL ASpECtS »

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« FRom SCIEntIFIC RESEARCH RESuLtS to tHE mAtH moDEL, mAnuFACtuRInG AnD ImpRoVEmEnt »

Innovations

PDC bit hydraulics pattern.

Design engineering and products manufacturing are fulfilled according to an individual arrangement for a particular customer, taking into account customer equipment and field lithology. Currently, our specialists can design and manufacture drilling tools of any complexity and modify bit design depending on the specific drilling application.

All the Companies’ innovations are targeted at fulfillment of Quality Policy which means maximum satisfaction of customer’s requirements and expectations and creating their confidence in the Companies’ products.

Continuous monitoring products quality at all stages of their life facilitates operational decision-making related to improvement of design parameters and manufacturing technology.

A team of highly skilled specialists develops and implements innovations in cooperation with scientific and research organizations.

Improvement of manufacturing technology includes selecting optimum equipment, optimizing technological processes, the production modes as well as selecting new materials with improved characteristics.

One of the key objectives of drill bit design is improving bit hydraulics. For this purpose, specialists of design bureau and research department analyze and select optimum quantity and location of nozzles for timely removal of cuttings from bottom-hole, prevention of their re-cutting with the cutting structure, ensuring cuttings evacuation from the hole through the annulus, preventing bit balling and providing cooling of the work areas of the cutting structure. Having our proprietary patented technical research and software developments enables us to manufacture highly competitive drill bits modified for customer specific applications.

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QuALIty mAnAGEmEnt SyStEm

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Quality Management System

« QuALIty IS GuARAntEED In ALL ASpECtS oF CompAny’S woRk »

A special place in the Quality Management System is traditionally and justly held by product quality control. Highly qualified personnel of Manufacturing Engineering Support and Technical Control departments, a number of high technology laboratories and services ensure undeviating meeting the product requirements that have been set before Volgaburmash, JSC and Uralburmash, JSC for many decades.

Quality is the main strategic objective of Volgaburmash and Uralburmash regulating all Companies’ management, production and marketing processes, starting from development of new bit designs meeting customer requirements to delivery of manufactured products to customer.

Volgaburmash, JSC and Uralburmash, JSC have implemented, certified and maintain Quality Management System (QMS) that complies with ISO 9001 requirements. Besides, Volgaburmash QMS has been certified according to API Spec.Q1 for more than 15 years. The Company also has implemented ISO 14001 standard (Environment management system) and British national standard BS-OHSAS 18001 (Health and Safety management system).

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Quality Management System

Advanced and constantly brought up to date equipment of the Companies’ laboratories and services guarantees quality control and assessment level meeting the International Standards as far as design solutions, materials, component parts and manufacturing processes.

From chemical analysis of highly complex materials, structural study, identification of grade, grain size, plating thickness to operational control in express laboratories and modification of technology processes of powder metallurgy, industrial rubber articles, chemical and heat treatment of bit component parts — this is by no means the complete list of methods and processes that are successfully carried out for the purposes of product quality control.

« DRILLInG tooLS oF Any CompLExIty, bIt DESIGn ImpRoVEmEnt »

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pRoDuCtS FoR ConStRuCtIon InDuStRy

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technopro

TechnoPro drill bits with sealed premium bearings up to 15 1/2`` (393,7 mm) with water or mud circulation are specially developed for water-well drilling, horizontal directional drilling and construction drilling. They give good drilling performance due to their improved reliability bearings and optimum cutting structures. TechnoPro bits have both friction and non-friction bearings. Friction bearings use anti-friction wear-resistant materials with silver plating.

TechnoPro

Product lineDiameter, in IADC code

(9 7/8)250,8Diameter, mm

TCNP 615

Roller Cone Bits Design Features

Central mudcirculation

Shirttail and legleading edgehardfacing

Leg protectionwith TCI cutters

Combined mudcirculation

Extended nozzles

Designation

Cutting structureThis product line can have either steel teeth or TCI. To increase steel teeth life, steel teeth are hardfaced with wear-resistant tungsten carbide based material. Depending on the rock hardness, either side surfaces or both side and end surfaces of steel teeth are hardfaced. The heel can be protected with tungsten carbide inserts. For additional protection against gauge loss, a near gauge of tungsten carbide inserts can be used.

Lubrication systemBit lubrication system is designed to compensate grease consumption and pressure during long-term operation. It consists of a grease reservoir with a rigidly mounted cap, a flexible diaphragm, a metal canister protecting the diaphragm from breakage, and channels to connect the grease reservoir with friction areas in bearings.

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Chisel inserts

Enhanced steelteeth hardfacing

Conical inserts

Other shapeinserts

Roller Cone Bits Design Features

Near gauge row (reamers)

Enhancedheel row

Diamond compacts in thenear gauge row (reamers)

Single gauge of tungsten carbidecompacts

Double gauge of tungsten carbidecompacts

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TechnoProBit diameter

Bitidentification IADC code

ThreadWeight,

kg Manufacturermm in GOST API

120,6 4 3/4 TCNP547 547 Pin З-76 2 7/8 Reg 9,5 Volgaburmash








152,4 6 TCNP215 215 Pin З-88 3 1/2 Reg 16,0 Volgaburmash

152,4 6 TCNP517 517 Pin З-88 3 1/2 Reg 16,0 Volgaburmash























TechnoPro Technical information

Set of nozzles for roller cone bitsBit diameter, mm Design number Nozzle ID, mm

95,3; 104,8; 108,0 R9531 7,9; 9,5; 11,1

120,6-127,0 for IADC codes 54x, 61x and 62x R6738 12,7; 14,3; 14,38,7; 12,7; 14,3

139,7 - 152,4 R3401 8,7; 11,1; 14,3

155,6 - 171,4 R1804 8,7; 11,1; 14,3

190,5; 200,0 -215,9; 222,3; 244,5 for IADC codes 54x, 61x and 62x

R0030R0030 (centr.)

12,7; 14,3; 15,912,7

190,5; 200,0 - 244,5 for other bit types R0030R0030 (centr.)

14,3; 15,9; 19,014,3

279,4; 295,3; 304,8; 311,1; 339,7; 349,2; 393,7; 444,5250,8; 269,9

R0101R0101 (centr.)R0030 (centr.)

19,0; 20,6; 20,615,912,7

406,4 R9819 (extended)R0101 (centr.)

15,9; 15,9; 15,915,9

368,3; 374,6; 381,0; 406,4; 431,8; 469,9; 490,0 R0101R0101 (centr.)

15,9; 15,9; 15,915,9

508,0 R0101R0101 (centr.)

19,0; 19,0; 19,015,9

660,4 R0101R0101 (centr.)

20,6; 20,6; 20,619,0

212,7 - 222,3 extended nozzles (steel teeth bits)Tech Spec 3664-034-

05749180-01

2018

1815

215,9 - 222,3 extended nozzles (TCI bits) 2018

1815

*Set of nozzles can be changed on customer request

Torque recommended for thread connectionsBit diameter API connectionthread Recommendedwrench torque

In Mm In Mm Ft•lbs кН•м

3 3/4 - 4 1/4 95,3 - 108,0 2 3/8 Reg З - 66 З000 - 3500 4 - 4,84 5/8 - 5 3/8 117,5 - 36,5 2 7/8 Reg З - 76 4500 - 5500 6 - 7,55 1/2 - 6 3/4 139,7 - 71,4 3 1/2 Reg З - 88 7000 - 9000 9,5 - 127 1/2 - 8 3/4 190,5 - 22,3 4 1/2 Reg З - 117 12000 - 16000 16 - 229 5/8 - 13 3/4 244,5 - 49,2 6 5/8 Reg З - 152 28000 - 32000 38 - 4314 3/4 - 26 374,6 - 60,4 7 5/8 Reg З - 177 З4000 - 40000 46 - 54

Roller cone bits diameter tolerances

Drill bit rated diameter, mm Tolerance, mm

From 44.4 up to and including 349.2 +0.8

Over 349.2 up to and including 444.5 +1.6

Over 444.5 +2.4

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FastDrillConstruction

ConstructionFastDrill bits are applied for full diameter drilling of vertical and directional wells. They are specially developed for using in construction and mining industries. ConstructionFastDrill bits can be successfully used while drilling exploration, degassing and production wells. Wear-resistant PDC-cutters allow to multiply the bits life and performance. Fluid discharge ports oriented towards the bottom hole efficiently clean the bottom hole and cool the bit.

FastDrillConstructionBit diameter

Bitidentification

ThreadWeight,


76 3 FDC313S Pin З-42 - 2,00 Volgaburmash

93 3 21/32 FDC313S Pin З-50 - 2,60 Volgaburmash

96 3 25/32 FDC313S Pin З-66 2 3/8 Reg 3,60 Volgaburmash

98 3 27/32 FDC313S Pin З-66 2 3/8 Reg 3,70 Volgaburmash

PDC Bits

(3)Product line Number of

gauge pads

FDC 3 13 SCutter size

Formation hardness

76Bit diameter, mm (in)

Designation

Formation HardnessS Soft formations Н Hard formations

SM Soft formations with medium interlayers НА Hard abrasive formations

SMА Soft abrasive formations with medium interlayers НЕ Hard formations with extra-hard interlayers

M Medium formations НЕА Hard abrasive formations with extra-hard interlayers

MА Medium abrasive formations Е Extra-hard formations

MH Medium formations with hard interlayers

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waterDrill

These steel-body bladed bits are designed for water-well drilling in soft formations with medium interlayers, with water or mud circulation. The bits have TCI and PDC as their cutting structure.

TCI Bits

WaterDrillBit diameter

Bitidentification IADC code

ThreadWeight,


114,3 4 1/2 WD413SM S233 Pin З-76 2 7/8 Reg 7,5 Volgaburmash

127,0 5 WD313S S233 Pin З-86 NC 31 8,9 Volgaburmash


134,0 5 9/32 WD313S S233 Pin З-86 NC 31 9,3 Volgaburmash

152,4 6 WD313S S233 Pin З-88 3 1/2 Reg 12,0 Volgaburmash


165,1 6 1/2 WD513S S233 Pin З-88 3 1/2 Reg 14,5 Volgaburmash





Designation

Formation HardnessS Soft formations Н Hard formations

SM Soft formations with medium interlayers НА Hard abrasive formations

SMА Soft abrasive formations with medium interlayers НЕ Hard formations with extra-hard interlayers

M Medium formations НЕА Hard abrasive formations with extra-hard interlayers

MА Medium abrasive formations Е Extra-hard formations

MH Medium formations with hard interlayers

Diameter, in

(5)Product line Number of

blades

WD 3 13 SPDC size

Rock hard-ness

127,0Diameter, mm

Torque recommended for thread connections

Connecting threadRecommended torque, kN•m

GOST API

З-66 2 3/8 4,0 - 4,8

З-76 2 7/8 6,0 – 7,5

З-88 3 1/2 9,5 – 12,0

З-117 4 1/2 16,0 – 22,0

З-152 6 5/8 38,0 – 43,0

З-177 7 5/8 46,0 – 54,0

Nozzle types for PDC bitsNozzletype

Nozzle ID, mm /in

5,6 6,4 7,1 7,9 8,7 9,5 10,3 11,1 11,9 12,7 14,3 15,9 17,5 19,1 20,6 22,2

7/32 8/32 9/32 10/32 11/32 12/32 13/32 14/32 15/32 16/32 18/32 20/32 22/32 24/32 26/32 28/32

22, ports * * * * * * *

27 * * * * * * * * * * * *

39 * * * * * * * * * * * * * * *

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DtH

DTH bits are designed for drilling blast holes with downhole hammers. Splined joint of the shank increases reliability and joint efficiency, provides quick tool change. The bits cutting structure consists of tungsten carbide spherical or ballistic buttons. Flushing grooves are designed for the most efficient bottom-hole cleaning.

DTHBit diameter

Designation

Shank Flushing grooves,

pcs. x mm

Weight, kg Manufacturer

mm in Compatible type

Height, mm

152,4 6 DTH-M5 F3S M50 259 3x20 16,1 Volgaburmash

152,4 6 DTH-QL5 C3S QL50 240 3x20 17,9 Volgaburmash

165,1 6 1/2 DTH-QL6C3S QL60 245,9 3x24 23,4 Volgaburmash

165,1 6 1/2 DTH-QL6 F2S QL60 245,9 2x24 23,6 Volgaburmash

171,4 6 3/4 DTH-QL6 F2S QL60 245,9 2x24 24,3 Volgaburmash

203,2 8 DTH-QL6 F2S QL60 245,9 2x24 27,5 Volgaburmash

DTH Bits

165,1 (6 1/2)Bit diameter, mm (in)

QL6 C3S

Shank type

Button shape

Number of ports

Face geometry

DTH-

Product line

Face geometry:F — flatC — concaveX — convex

Button shape:S — sphericalB — ballistic

Designation

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Sections kits

Roller-cone bit sections can be used for assembly of various types of hole-openers.

Sections kits

Sections kitsBit diameter

Bitidentification IADC code Weight, kg Manufacturer

mm in

139,7 5 1/2 SLH617 617 13,5 Volgaburmash

165,1 6 1/2 SLH517 517 20 Volgaburmash


Sections kitsBit diameter

Bitidentification IADC code Weight, kg Manufacturer

mm in

311,1 12 1/4 MTR515 515 87 Volgaburmash



311,1 12 1/4 MTR537 537 96,9 Volgaburmash


508,0 20 GRDP515 515 330 Volgaburmash

165,1 6 1/2 SLHP637 637 19 Volgaburmash




444,5 17 1/2 GRDP535 535 234 Volgaburmash


139,7 5 1/2 SLHP547 547 13,5 Volgaburmash

139,7 5 1/2 SLHP437 437 13,5 Volgaburmash





444,5 17 1/2 GRDP115 115 234 Volgaburmash


Designation

Product lineDiameter, in IADC code

(8 1/2)215,9Diameter, mm

MTR 625

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IADC code description for roller cone bits

Support Information

Example: 41

32

73

First code character describes bit type (milled teeth or TCI cutting structure):

• 1 - 2 - 3 — Milled teeth bits (from very soft to very hard formations)

• 4 - 5 - 6 - 7 - 8 — TCI bits (from very soft to very hard formations)

1

Second code character describes formation (from very soft to very hard formations), bits differ in number and size of cutters/inserts

2

Third code character describes bit bearing:

1. Standard open roller bearing

2. Standard open roller bearing, air-cooled

3. Standard open roller bearing with gauge protection

4. Sealed roller bearing

5. Sealed roller bearing with gauge protection

6. Sealed friction bearing

7. Sealed friction bearing with gauge protection

8. For directional drilling

9. Special

3

IADC code description for pDC bits

Example: 12

23

34

Bit body:

• S–steelbody

• M–matrixbody

1

S1

Bit body

Bottom hole coverage

Cutting structure

Bit profile

Bottom hole coverage:

1. 25% - 50%

2. 50% - 75%

3. 75% - 90%

4. more than 90%

2

Cutting structure:

1. cutter size more than 24 mm

2. cutter size 14 – 24 mm

3. cutter size 8 – 14 mm

4. cutter size less than 8 mm

3

Bit profile:

1. Short fishtail

2. Short profile

3. Medium profile

4. Long profile

4

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Of using Volgaburmash and Uralburmash drill bits at different stages from drilling through casing elements to pulling the bit to the surface, including optimizing bit operational parameters and troubleshooting.

packing and transportationReasonable precautions should be taken in the course of transportation of the bits. At the plant, the bit is packed into a wooden or cardboard box to prevent its damage during transportation process. The bit has to remain packed until it is used. Dropping packaged bits is prohibited. When a bit is moved without package, it is necessary to place a wooden or rubber pad under the bit face. It is also necessary to avoid hitting thread connection. Remember that PDC bits weight more than roller cone bits of the same diameter.

pre-operational phase• Preparationofabitiscarriedoutonthedrillsite,afterthepreviousbitispulledout.Whenpullingoutabit,

check if there are tight sections in the borehole. If a tight section is revealed, ream the borehole to avoid problems further on.

• Afterpullingoutthebit,describeitswear.Payspecialattentiontothebrokenorlostteeth(cutters),brokenor lost nozzles, broken blades, broken or lost cones, any mechanical damages. If there are any metal fragments in the well, there is a danger of damaging a new bit when it starts therefore it is recommended to use the tool for cleaning the bottom-hole.

• Whenanewbitisprepared,therotarytableshouldbecovered.Forarollerconebit,youmayuseabitbreaker, for a PDC bit, you may use a wood panel or screen fully covering the well mouth. Fix the bit breaker to a PDC bit before placing it to the table. Take precautions when lifting a bit.

• Makesurethatconnectingthreadiscoveredwithgrease.

• Make-uptorqueshouldbeselectedaccordingtothethreadsizeandtype.

operating procedure

Lifting heavy objects

Support Information

Recommended torque

Connecting threadTorque recommended, kN/m

GOST API

З-50 - 2,1 – 2,4

З-66 2 3/8 4,0 – 4,8

3-76 2 7/8 6,0 – 7,5

З-86 NC 31 9,6 – 11,6

З-88 3 1/2 9,5 – 12,0

З-117 4 1/2 16,0 – 22,0

З-133 NC 50 15,0 – 17,0

З-152 6 5/8 38,0 – 43,0

З-177 7 5/8 46,0 – 54,0

opERAtIonAL pHASERun-in-hole operation• when the bit is made up, carefully, avoiding shocks run the bit through rotary table into the umbrella

and assembly of blow-out preventers. Remember that hole rugosity and shoulders are dangerous for PDC cutters. Inside the casing such places are the conductor and drilled out casing shoe, in the open hole there can be shoulders, sharp variations of the hole trajectory, tight sections. BHA stiffness is also important.

• Smoothly run the drill string into the open hole without slacking off or relief more than 5 tons. Ream the tight sections and hole shoulders if necessary.

• If a significant part of the borehole should be reamed, it is recommended to use a roller cone bit instead of a PDC bit.

• The last drill pipe stand should be run in the hole at limited speed. If BHA relief is more than 5 tons you should lift up the bit, start the mud pump, clean the well for 10-15 minutes and with normal mud circulation run the bit to the bottom hole while reaming bottom hole area.

• You should remember that when reaming, a PDC bit is apt to lateral vibrations which may result in the damage of cutters.

Reaming and hole-opening in previously drilled sections• Ream the bore hole at low WOB and RPM.

• Circulation rate should be maximal allowed.

• When reaming in the sections with hard and abrasive formations, RPM should be reduced.

• For rotary drilling, use WOB = 0.5-2.5 tons and RPM = 40 – 60rpm.

• When drilling with downhole motors, use similar mode of minimal WOB and minimal circulation rate allowed.

• When drilling the bore hole, WOB is not recommended to be higher than 2 tons to avoid damaging the cutting structure.

• Control the torque when reaming in sections with abrasive formations. The torque mainly increases when PDC cutters on the gauge are seriously worn or a roller cone bit loses its diameter which results in bit body or BHA elements contacting the bore hole walls.

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Drilling outMethods of drilling out shoe tracks (ST) and casing hardware with PDC or roller cone bits do not differ a lot. To prevent bit damage, please follow the recommendations below:

• Shoe tracks (ST) and cement plugs are drilled out with maximal circulation rate possible and minimal WOB.

• During ST drilling out, drill string is reciprocated from time to time which facilitates bit cleaning from cuttings.

Reciprocation should take place every 5-10 minutes of drilling or every 5-10 cm drilled per 1-1.5 m of the kelly. If ROP suddenly drops, repeat this procedure until the bottom hole and the bit are fully cleaned.

• Monitor pipe pressure to avoid plugged nozzles.

• Modify RPM if vibrations occur or torque suddenly leaps.

• If a cement plug turns over, try to relieve the drill string onto it without rotation. Increase WOB or circulation rate (pipe pressure should increase by 15-20 atm.). Start rotating the drill string at 40 – 60 rpm. Repeat this procedure till you are sure that the plug is broken.

Forming new bottom hole profile and bit breaking in• When starting work with a new bit, it is important to form the new bottom hole profile according to the bit

geometry. The bit efficiency and ROP depend on this quality of this procedure.

• You should be especially careful when forming the bottom hole profile, if geometry and type of the new bit differ essentially from the previous one – a PDC bit after a roller cone bit or vice versa.

• You should remember that a roller cone bit usually makes a larger hole diameter than a PDC bit

• 1.5 – 2 meters above the estimated bottom hole, start mud circulation with a predetermined optimal rate. Recommended RPM = 40 – 60.

• Increase of counter torque and WOB indicates reaching the bottom hole. WOB should be limited to 2 tons.

• After reaching the bottom hole, the tool should be lifted up to 15 – 30 cm above the bottom hole and the bottom hole should be cleaned for 5 minutes to remove the pad of cuttings.

• Then return to the bottom hole and start drilling with WOB not exceeding 2 tons. Maintain this load while drilling the distance equal to the length of the bit.

• Maintain minimal and steady torque of the bit.

• Continue the part load mode chosen to form the new bottom-hole profile till the bit runs the distance equal to the length of the bit. Then you may switch to the mode with optimal parameters.

DrillingOperating parameters and drilling modes of roller cone and PDC bits are indicated in the bit passports. Particular operating parameters of the bits are always defined according to lithology information and well engineering data.

• In soft formations, the highest possible RPM and relatively low WOB are recommended.

• In medium formations, medium WOB should be maintained at medium RPM. With wear of the cutters, it is recommended to increase WOB.

• In hard formations, the most efficient is the drilling mode with medium to high WOB and low to medium RPM.

• It is not recommended to apply the top values of all drilling parameters at the same time. Drilling parameters are indicated in a bit specification.

• Avoid WOB drops as supplying the load jerkily by 3-5 tons results in steep increase of torque on the bit which in turn leads to pipe pressure jumps and motor shutdown, it may also result in bit balling.

• To determine WOB in the vertical bore hole, before you start drilling, you should measure the bit’s hook weight with pumps on. In high ROP applications, the bit’s hook weight should be measured while the drill string is being run down to the bottom hole with estimated ROP. This is because the true WOB may be lower than the measured weight of the bit by the value of hydraulic lift (with pumps on) applied from under the bit. Hydraulic lift has an effect on any bit type which creates differential pressure due to fluid flow between the tool face and the rock.

• For directional or horizontal bore hole optimum WOB is defined by differential pressure (injection pressure difference when the bit is “on bottom hole” and “above bottom hole”). Recommended minimum differential pressure is 20 atm. When drilling remember to control WOB by means of stand pipe differential pressure maintenance.

• Whenusingdownholemotors,allotherthingsbeingequal,bitperformanceindicatorsaregovernedbythetechnicalcondition of the motor. That is why before BHA is run down the hole, please check the actual technical parameters of the motor which are defined by means of benchmark tests after each repair work. Benchmark test results are indicated in the bit certificate, including moment of force at the output shaft (in operating mode and in full power condition); output speed (in no-operation mode, in operation mode and at maximum feed allowed); differential pressure of the motor (in no-operation mode, in operation mode and in braking mode).

optimizing drilling parameterstwo test requirements:

• Conducting a test is only possible after the bit breaking in;

• The formation is relatively homogeneous.

passive test:

• Haul WOB to zero, to avoid hanging up of the tool.

• With medium RPM, create maximum WOB allowed and fix the travelling block.

• Constantly register changes of WOB, write down the time it takes to reduce WOB (hook weight increases) by a certain value (for example, by 2 tons) depending on bit diameter and type.

• Continue record of time periods it takes to decrease WOB by identical values until ROP doesn’t become considerably less in comparison with the beginning of the test.

• Evaluate WOB, changing of which by the set value took the shortest time. This WOB is optimum for this RPM.

• Repeat the test for other RPM values up to the maximum allowed (for the bit and the drive).

• Values at which time to reduce WOB by a certain value will be the smallest will be an optimum combination of RPM and WOB.

• The passive test can be stopped if after WOB is applied it does not decrease. It can be indicative of insufficient WOB supply.

Active test:

• Set the average optimum bit RPM.

• Set the lower level of WOB based on the optimum range and record ROP during 5 minute interval.

• Record ROPs several times, each time applying greater WOB.

• Repeat this till you reach the upper level of optimum range of WOB.

• Identify the range of parameters at with maximum ROP.

• Repeat the test several times with various WOB values.

• After optimum WOB value is identified by means of its increase and decrease, ROP can be optimized.

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troubleshootingBit life directly depends on compliance with the recommended operational modes indicated in the bit specification, nevertheless, for a number of reasons, the bit can fail before the estimated run life, therefore it is very important to assess the problem in due time and to make recommendations on its solution, i.e. to carry out troubleshooting.

On the surface, the following parameters can be indicative of a failure:

• Pressure

• Torque

• RPM

• Axialloading

• Flowrate

• ROP

• Vibration

• Rocksamples

Each of the listed signs of malfunction can be caused by several factors. Some factors are very specific. Carefully study the issue and pass to stage-by-stage elimination of its reasons.

Change of working pressure

pDC bit

• Bit balling

• Mud ring in the annulus

• Flow rate change

Roller cone bit

• Bit balling

• Flow rate change

Additional reasons:

• Flowrateincrease

• Increaseofdrillingmudweightorviscosity

• Pluggednozzle

• Narrowingoftheannularspace

• Ringwearorcoredbit

• Bitballing

Reasons of pressure decrease:

• Flow rate decrease

• Decrease of drilling mud weight or viscosity

• Washout of the tool

• Gas mud

• Gas blowout

• Mud loss

• Lost nozzle

• Drill pipe failure

torque

Increase

• WOBincrease

• Rockalteration


• Bearingfailure

• Gaugewear

Decrease

• WOBdecrease

• Rockalteration

• Bitwearordamage

• Bitballing

Vibrations

• Alternation of formation layers or fractured formation

• BHA hanging up when tripping down

• Excessive WOB

• Gauge wear

• Foreign bodies in the well

• Intake or hole deviation

RopRop increase

• Rockalteration

• Mudweightdecreaseorpropertiesimprovement

• Porepressureincrease

• WOBoptimization

• RPMoptimization

• Cleaning(hydraulics)optimization)

Rop decrease

• Rockalteration

• Mudweightincreaseorpropertiesdeterioration

• WOBisnotoptimized

• RPMisnotoptimized

• Poorbitcleaning(hydraulics)

• Worncuttingstructure

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Rop variations

• Alternationofformationlayersorfracturedformation

• Bitballing

• LackofBHAmovement

Flow rateFlow rate increase at constant pump pressure

• Washoutofthetool

• Gasmud

• Gasblowout

• Mudloss

• Decreaseofdrillingmudweightorviscosity

Flow rate decrease at constant pump pressure


• Pluggednozzleorwashinggroove

• Bitballing

• Increaseofdrillingmudweightorviscosity

• Ringwearorcoredbit

Removal of bit balling and sticking clayIn soft hydrophilic clay when using water based mud, clay hydration and sticking to the bit are likely to occur which results in drop of drilling efficiency.

balling symptoms are:

• significantdropoftorque,

• significantdropofROP,

• increaseofpipepressure.

For cleaning the bit the following steps should be taken:

• Liftthebitby5cm(2in)abovethebottomhole.

• Injectthemudatmaximumrateallowedfor5–15minutes.

• Whiledoingthat,increasebitRPMtothemaximumpossiblefor1minute,repeatthisstepa1minuteintervals.

• Afterthespecifiedprocedure,setnewdrillingparameters:

1. Set maximum possible RPM.

2. Set maximum possible flow rate.

3. Set WOB value at 80% of the value at which bit balling occurred.

Remember that to identify the main reason of a failure it is necessary to check several parameters.

Drill bit pull outDrill bit pull out is caused by several reasons:

• Reachingthetargetdepth

• Specifiedsection

• Changingthebitorotherdownholetoolswiththechangeofformations

• Incaseofdirectionaldrilling,reachingseveredoglegorchangeofformations

• Incaseofcoresampling–reachingthetargetdepthorformation

• Suddenincreaseordecreaseoftorquefornoapparentcause

• Lateralortorsionalvibrations

• SuddendropofROP.

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Evaluation parameters

• Cutting structure • Bearing • Bit diameter • Comments

• Inner rows

• Outer rows

• Dull aracteristics • Location • Bearings /

Seals• Gauge wear 1/16

• Other dullcharacteristics

• Reason pulled

(I) (O) (D) (L) (B) (G) (O) (R)

Drill bits dull grading

(I) Inner rows (2/3 of the bit diameter)

(o) outer rowColumns (I) and (O) describe cutting structure condition linear scale 0 - 8

For milled teeth bits:: Measuring tooth height reduction due to abrasive wear or chipping 0 – tooth is not worn 8 – wear out

For tCI bits: Counting lost, worn out or chipped inserts

0 – no lost, worn out or chipped inserts 8 – all inserts are worn out, chipped or lost

For pDC bits: Counting lost, worn out or chipped cutters 0 – no lost, worn out or chipped cutters 8 – all cutters are worn out, chipped or lost

(D) Dull characteristicsOnly applied to cutting structure

*BC – broken cone BF – bond failure BT – broken cutters/teeth BU – balled up *CC – cracked cone *CD – cone dragged CI – cone interference CR – cored CT – chipped cutters ER – erosion FC – flat crests of steel teeth HC – heat checking JD – junk damage *LC – lost cone LN – Lost Nozzle LT – Lost Cutters OC – off-center wear PB – pinched bit PN – Plugged Nozzle/Flow Passage RG – Rounded gauge RO – Ring Out SD – shirttail damage SS – self-sharpening TR – tracking WO – washed out WT – worn cutters NO – no wear

* - Indicate cone number(s) in column (L)

(L) LocationFor roller cone bits

N – central rows Cone number(s) M – middle rows 1 2 3 G – gauge rows A – all rows

For pDC bits C – cone N - nose T – taper S – shoulder G – gauge A – all areas

(b) bearings/sealsopen bearing – linear scale from 0 to 8 describes bearing service life

0 – bearing capacity is not used

8 – bearing capacity is fully used

Sealed bearing E – seals are not damaged

F - seals damaged

N – it is not possible to assess wear

X – PDC bit, no bearing

(G) Gauge I – In Gauge

1/16» – 1/16» Out of Gauge

1/8» – 1/8» Out of Gauge

1/4» – 1/4» Out of Gauge

(О) other dull characteristics (See column D)

(R) Reason pulled BHA – Change Bottomhole Assembly

DMF – Downhole Motor Failure DTF – Downhole Tool Failure DSF – Drill String Failure DST – Drill Stem Test DP – Drill Plug CM – Condition Mud CP – Core Point FM – Formation Change HP – Hole Problems LIN – Left in Hole HR – Hours on Bit LOG – Run Logs PP – Pump Pressure PR – Penetration Rate RIG – Rig Repair TD – Total Depth TW – Twist Off TQ – Torque WC – Weather Conditions

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Product Catalogue for Construction Industry

Site

www.vbm.ru www.vbm.ru

Contacts

Volgaburmash, JSCGroznenskaya St. 1, Samara, 443004, Russia

Tel.: +7 (846) 300-8000

Fax: +7 (846) 300-8000

www.vbm.ru

E-mai l: ma i [email protected]

Uralburmash, JSCVolodarskogo St. 10, Verkhniye Sergi, The Sverdlovsk Region, 623070, Russia

Tel.: +7 (34398) 2-42-21

www.vbm.ru


Sales Representative – Samara Drilling Tools, LLC

Groznenskaya St. 1, Samara, 443004, Russia

Tel.: +7 (846) 300-8000

Fax: +7 (846) 300-8000

www.vbm.ru


At our web-site you will find more detailed information about our range of products, drilling modes and operating conditions.In the section “Products for Specific Fields” you can find optimal designs, make selection using filter and then send your request for the necessary products to our specialists.

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Documents

· Quality Management System (QMS) that complies with ISO 9001 requirements. Besides, Volgaburmash QMS has been certified according to API Spec.Q1 for more than 15 years. The Company