A Technological Leap through
Automated Directional Drilling in the
Rotary Mode -
Examining the Advantages
of
Baker Hughes INTEQ
© 1998 Baker Hughes INTEQ
All rights reserved.
Conventional Technology
z Directional Drilling Motor + MWD behind
z requires oriented drilling to change
drilling direction
– reduced rate of penetration
– impaired cutting transportation
– poor hole cleaning
z directional changes are getting difficult in
long or complex wells
z often roller cone bits required to carry out
directional work
© 1998 Baker Hughes INTEQ
All rights reserved.
AutoTrak
Non rotating
Sleeve “Triple Combo”
MWD
Rotating Drive
Shaft
Formation Evaluation
“Gamma Ray + Resistivity”
Non rotating Sleeve w/
Steering ribs & Inclination Sensors
© 1998 Baker Hughes INTEQ
All rights reserved.
Detailed Configuration
Near Bit Alternato Alternato Master /
r,
Inclination, Near r/ Memor Vibratio Batter Direction
Pulser,
Bit Actuator Downlink y n yMod al Module
Oil pump
Module Module Module Module ule
Non Pulser / 8.3/8" Multi Propagation Short
Rotating Alternato Stabilis Resistivity / NMCSD
Steerable r Sub er Gamma Ray Sub P
Stabiliser
Optional Triple
Combo Optional Downhole
Motor
Modular Modular NMCSD 6.3/4” M1XL Ultra
Density Neutron P Series
Lithology Sub Porosity Sub
© 1998 Baker Hughes INTEQ
All rights reserved.
Steering Principle
Static lateral force, dynamic control
High Side
High Side
Bearing Housing Sleeve Orientation
Sleeve Direction
P2
Bit Side Force
=
P3
P1 Magnitude
Drive Shaft
© 1998 Baker Hughes INTEQ
All rights reserved.
Control principle
Two way communication
z Automated Steering of the
downhole tool while
drilling in rotary mode
z No interruption to drilling
z Bypass valve at the stand
pipe creates coded flow
rate variations
z Commands for Steering
and to control all MWD /
LWD operation
© 1998 Baker Hughes INTEQ
All rights reserved.
Unique Features
➤ Integrated MWD/LWD sensors
z Integrated in the tool
– Multiple Propagation Resistivity, 2
frequencies
– Gamma Ray
z Supports Optionial FE subs
– Neutron
– Density
– Pressure
– Drilling Dynamics
z Two way communication - Confirmation
z Control & Monitoring in Real time
© 1998 Baker Hughes INTEQ
All rights reserved.
8 1/4” Technical Data
• Borehole Diameter: 12 ¼”
• Flow Rate: 525-1100 GPM
• Max. Operating WOB: 40 t (88,000 lbs)
• Max. Operating. Torque 45 kNm
• Max. Bit RPM: 250
• Tool Length: 12,2 m / 40 ft.
• Dogleg Severity: 0 - 6.0°/100 ft
• Operating Temp.: 150°C / 300°F
© 1998 Baker Hughes INTEQ
All rights reserved.
6 3/4” Technical Data
• Borehole Diameter: 8.1/2"
• Flow Rate: 370-640 GPM
• Max. Operation WOB: 25t (55,000 lbs)
• Max. Operation Torque 17 kft-lbs
• Max. Bit rpm: 250
• Tool Length: 11.2 m (37 ft)
• Dogleg Severity: 0 - 6.5°/100 ft
• Operat. Temperature max.150°C / 300°F
© 1998 Baker Hughes INTEQ
All rights reserved.
Operational Experience - July 1998
Total footage drilled
120000 ft (36500m)
© 1998 Baker Hughes INTEQ
All rights reserved.
Case History #1: Offshore Norway
ERD well, Geosteering
z 70% ROP increase compared to offset wells
z unusual small overload when pulling upwards
z very good borehole cleaning, reduced circulation times
z 3,2 days saved against plan
Run #1 - Build from 45° to 87° Run #2 - Entry in the
inclination w/ 3.5°/30m , 650m Offshore Norwegian,
reservoir, Statfjord
build to 87°
Tangent, drop w/ 1.5°/30m to the Field
inclination, hold inclination for
top of the reservoir 1000m through the reservoir
© 1998 Baker Hughes INTEQ
All rights reserved.
Case history #2: Offshore UK
z complex 3D-Profile
– incl. 80° azimuth change
z 40% ROP increase compared
to offset wells
z Section drilled with one
TX445 bit, 1008m
– w/o AutoTrak 3-4 bits
were planned
z 136,7 drilling hours ,
170,0 circulation hours
© 1998 Baker Hughes INTEQ
All rights reserved.
Case history #3: Offshore Norway
AutoTrak + Triple Combo
z Achievements:
– The Longest Horizontal Section in the Field - 2710m
– Highest effective ROP achieved in this section
– Only 2 PDC bits used
– Total Savings: 7 days & 1.4 Million USD
20
15 18
17
Offset
10 13,4
10 AutoTrak
5 7 2
0
Effective No. of No. of
ROP Bits days
© 1998 Baker Hughes INTEQ
All rights reserved.
Case history #3: Offshore Norway
Achievements:
– The Longest Horizontal Section (2,708 m) in Troll
Field
- 200m longer than before
– Highest effective ROP achieved in this section
– Only 2 PDC bits used
– Total Savings: 7 days & $1.4 Million
2000
AutoTrak
1500 w/PDC Bit
Meters
1000 Tri Cone
500
Conventional
0 BHA w/PDC
© 1998 Baker Hughes INTEQ
All rights reserved.
Longest Bit Runs In This Field
Summary
z 3D Control During Constant Rotation
z Two way communication
– Control all MWD/LWD parameters
– Modify/new directional targets
z Automated Directional Drilling
– Drill automatically towards targets
programmed into tool
– Automatically holds inclination when
reaching target
z One Integrated Tool
© 1998 Baker Hughes INTEQ
All rights reserved.
Conclusion
z Technology leap through Rotary Closed
Loop Systems
z Better reservoir development with less
wells and platforms
z No Sliding
© 1998 Baker Hughes INTEQ
All rights reserved.
