PREMIUM PDC Drill Bits: Superior performance for the most challenging applications

South AmericaUT Cobit-BesteBitBogota, ColombiaTel: 57-898-5116E-mail: sales@bestebit.com

Middle East & N. AfricaAletqan Well DrillingEquipment Trading LLCDubai, UAETel: 971-56-297-5955E-mail: sales@bestebit.com

Europe & Central AsiaHi-Tech District, ChengduSichuan, China 610041Tel: 86-28-85311882E-mail: sales@bestebit.com

North AmericaBesteBit, LLCConroe, Texas, USATel: 1-936-441-1220E-mail: sales@bestebit.com

South East AsiaOPS Oilfield Equipment Services LimitedChatuchak, Bangkok 10900 ThailandTel: 66-2-966-2777 Ext. 702E-mail: sales@bestebit.com

Chengdu Best Diamond Bit Co. Ltd. (BESTEBIT)No. 789 Keyuan South 2nd Road

Hi-Tech. District, Chengdu, China 610041

Phone: +86 28 85311882 Fax: +86 28 85312155

www.bestebit.com

South America

South East AsiaMiddle East & N. Africa

HQ, Chengdu, ChinaNorth America

Design Optimization Process

Document Lessons& Case History

Field Testing & Post Run Report

Design:- BitScan- Force Balance- CFD / FEA

Identify Target Well Objectives

BESTE ROCK (RMA)

Review Offset: - Parameters- Bit Records- Formations - BHA

Every Trident design is the result from BESTEBIT’s continuous 360 degree optimization process

01Step

04Step

02Step

05Step

03Step

06Step

6

5

4 3

2

1

Starts with reviewing all available information. The better the data quality, the better the solution. Thus, it is important to work with the Drilling Engineers to understand how relevant the offset data is to the target application.

Using BitScan Software to engineer a bit with the required features to help overcome the offset issues and achieve the target objectives.

The software benchmarks UCS, CCS and generates three indices: Balling, Abrasion & USC Rattiness. Future revisions will include IADC matching vs UCS. Operating parameters and vibrations logs can also be plotted to better understand formation behaviors and bit performance or Power Curves.

Run the BESTEBIT drill bit in the intended application. Gather data and qualify if the drilling objectives were met. Evaluate the bit performance, parameters and formation hardness with BESTE ROCK software. Generate a bit report with dull photos, DD comments and offset performance benchmarks.

Work with the Drilling Engineer to fully document and rank the objectives or performance qualifiers.

Document the lessons learned as to why or why not the objectives were met. Based on current technology, recommend changes to: bit design features, BHA and/or parameter.

Since this is a continuous 360 degree optimization process, all the information is fedback into Step 01 & the process starts over to achieve additional performance gains and value to the customer.

TRIDENT TM PDC Cutters

Premium next generation cutters

Engineered Improvements:

TRIDENT TM

PDC CuttersLonger bit life, deeper intervals, faster ROP and higher TD success rate.

Directional Bit Profile

Bit profiles are customized to meet the BHA and application requirement.

Directional Gauge Pad Design

Custom gauge pad designs offer flexibility to match the bit to the target Dog Leg.

Depth of Cut Control

DOCC Management smooths out downhole torque fluctuations, providing superior directional control on motor and RSS.

Feature Benefit & Advantage

Short Shank

Reduces the distance between the Bit-to-Bend or RSS steering unit, thus generating higher side cutting forces to achieve high Dog Legs.

Anti-Balling & CFD

Impact resistance

Thermal degradation

Abrasion wear resistance

Eliminates the “Dead Zone” by mechanically forcing cuttings into the CFD fluid path for faster ROP in balling formations.

ARMOR Hard Facing& Improved Matrix

Higher wear resistant body materials significantly increase operating hours for longer runs.

TRIDENT TM Feature Benefits

01

02

03Conventional Technology

High Cobalt & Low Pressure

TRIDENT Technology Low Cobalt & High Pressure

Wear Resistance

00

2

2

4

6

8

10

12

4 6 8 10 12

Imp

act Resistan

ce

T1

T2

T3T4

TRIDENT TM PDC Cutters

• Comprises four application-specific PDC cutters• Match cutter type with primary failure mode• Proprietary diamond blends & synthesis• Low cobalt concentration without leaching

Thermal

Impact Abrasion

T1 - Impact Resistance

T2 - Impact & Abrasion Resistance

T3 - High Abrasion Resistance

T4 - Extreme Abrasion Resistance

TRIDENT TM Cutter Summary:

• Comprises four application-specific PDC cutters • Employs proprietary diamond grits and ultra-high pressure synthesis process• Produces low cobalt concentration without leaching • Matches cutter to primary failure modes • Delivers high impact/abrasion resistance • Provides excellent thermal stability • Drills more footage per run • Lowers cost per foot

Trident Cutters – BESTEBIT’s latest cutter technology to improve both wear and impact resistance. Commer-cially released in Mid-2016

Directional Bit Profile – Selected from a variety of proven bit profiles to meet the BHA & application requirement.

Directional Gauge Pad Design – We can quickly modify the bit’s gauge pad configuration to meet the DL objec-tives.

Depth of Cut Control – An excellent feature to reduce

vibrations and assist with directional control.

Short Shanks – Shorter bit lengths for high steering forces and dog legs on motor & RSS.

Anti-Balling & CFD – A combination of technologies for proven ROP gains in balling prone applications.

ARMOR hard facing & Improved matrix – With new cutters lasting longer than ever, the Steel & Matrix body materials also need to improve to yield higher drilling hours.

Directional Bit Profile

Directional: Gauge Pad Design

Steerable Index Profile Height Cone Angle

Level 1

Level 2

Short Shank

Level 3

Medium

Medium

Short

Deep

Shallow

Shallow

Depth of Cut Control Technology

Gauge Pad FeaturesAnti-Balling Feature

Customized Torque

BESTEBIT offers a wide range of gauge configurations, depending on the requirements for: Dog leg and/or Gauge pad wear resistance.

A small dome contour in the center, removes the “Dead Zone” and thereby pushes formation into the fluid path, effectively cleaning the bit and reducing bit balling for faster ROP.

Hydraulics: CFD & Anti-Balling Feature

Improved Materials: Hard Facing & Matrix

Location Non Optimized Partially Optimized

Cone

Blade Front

Junk Slot

Reverse flow

Low flow

Scattered flow

Low flow

Low flow

Improved flow

Optimized

Full coverage

Full coverage

Parallel flow paths

CFD

• Reduces Erosion• Higher Hours

• Decreases Bit Balling• Faster ROP

StandardPDC

WOB

Torq

ue

Depth of Cut Control Technology

Depth of Cut (DOC) Control Technology is an excellent feature to reduce vibrations and assist with directional control on motor & RSS. As shown in the graph (WOB vs. Torque), the Engineering team can design the DOC Control feature to match the application’s wide DOC range.

Passive Step Active 1

ConventionalGauge

Tangent Orient

Active 2 Active 3

Step Gauge & Bit Tilt

RSS & MotorGauge pad relief allows thebit to tilt and change direction.

Matrix

Improved Matrix

• Higher erosion resistance

• Increased drilling hours

• Reduces Lost Cutters & Ring Out

• Higher TD success

Standard

Improved

Hard Facing

ARMOR Hard Facing

• 40% higher carbide density

• Longer hours in abrasive formations

• Pushing steel body into matrix applications

Standard

Improved+62% Hours

12” T1665 on Rotary Steerable

USA Onshore

Middle East Offshore

53%

8%

14%

25%

1 x TRIDENT Bit =

36 Cutters

53% Broken & Chipped

4Sections

4,290 mDrilled

94.5 hrIADC

10Sections

9,708 mDrilled

240 hrIADC

45% Less Broken & Chipped Cutters

12 ¼” Cutter Durability Comparison. Primary Dull Characteristic.

12 x Offset Bits=

432 Cutters

2% 2%

36%

7%13%

40%

Performance:

12% Faster ROP

10% More Footage

12% Lower Cost per Foot

BESTEBIT Competitor (Average top runs)

Footage Drilled Vs Bits Usage

BESTEBIT

Footage Per Day Vs Bits Usage

9 7/8” T1944

Savings:

+1 Bit Per sections

+2 DaysDrilling

> $60,000Savings

*Longest Distance Drilled

Competitor Bits Used Per Section

Bit

s U

sed

Per

Sec

tio

n

Foo

tage

Per

Day

(ft)

0

100

200

300

400

500

600

0

1

2

3

4

5

6

Bit

s U

sed

Per

Sec

tio

n

Foo

tage

Dri

lled

(ft)

0

1000

2000

3000

4000

5000

6000

0

1

2

3

4

5

6

ROP Distance Drilled

(ft/

hr)

0

15

30

45

60

BESTEBIT Competitor (Average top runs)

(ft)

0

500

1000

1500

2000

Non Optimized Partially Optimized

ROP

Cost Per Foot

Savings

20% Faster

20% Lower

$33,200

29% Faster

17% Lower

$58,600

Middle East Offshore

Competitor

BESTEBIT

ROP

CPF

UAE Offshore

16” T1679 on Steerable Motor

8 1/2” T1389 on Rotary Steerable & Motor Performance:

Savings:

193% Faster ROP

17%More Footage

60%Less Drilling Hours

$400,000Savings

Saves 2 Trips & 2 Bits

ROP (ft/hr)

BESTEBIT

Drilling Hours

Competitor

Mea

sure

d D

epth

(ft)

100 20 30 4011,250

11,000

10,750

10,500

10,250

Mea

sure

d D

epth

(ft)

240 48 72 9611,250

11,000

10,750

10,500

10,250

CP

F ($

/ft)

Foo

tage

Dri

lled

(ft)

2400

2500

2600

2700

2800

2900

3000

0

20

40

60

80

100

120

Footage Drilled Vs Cost Per FootFootage Drilled Vs ROP

RO

P (f

t/h

r)

Foo

tage

Dri

lled

(ft)

2400

2500

2600

2700

2800

2900

3000

0

20

40

60

80

100

120

www.bestebit.com

Reliability - Durability - Consistency

Thailand Onshore