6-3/4-in. AutoTrak G3 HT

Technical Data S ummary
6-3/4-in. AutoTrak G3 HT-175 RCLS
Building on the success of the most
technologically advanced Rotary Closed Loop
System (RCLS), the AutoTrak™ G3 HT-175
RCLS encompasses the latest levels of
MWD/LWD development in a rugged modular
design and able to work in high-temperature
environment up to 347°F (175°C). This
system opens new opportunities in all aspects
of directional drilling, including both
geosteering and extended reach applications.
The steering head can automatically steer
itself during continuous rotation of the drill
string with changes to the well trajectory
communicated to the tool from surface while
drilling ahead. Near to Bit Directional,
Azimuthal Gamma Ray, Multiple Propagation
Resistivity, real time pressure and vibration
measurements are included in the AutoTrak
G3 HT-175 System. Data transmission is
reliable and simple without the need to stop
drilling for sending and receiving commands.
This significantly reduces the NPT associated
with directional drilling.
The AutoTrak G3 HT-175 System is currently
drilling complex 3D profiles ensuring a high
borehole quality in thousands of applications
around the world, saving money, and
increasing production rates. The AutoTrak G3
HT-175 innovative design takes into account
all the challenges present in the most
demanding rotary-steerable and LWD
applications for reliable operations and
reduced NPT. Our proprietary multiplepropagation resistivity sensor design provides
the most accurate measurements in the
industry. The AutoTrak G3 HT-175 Service
combines an integrated sensor section with a
downhole power and communications module
and the Advantage™ surface system to
deliver optimal directional control, accurate
formation evaluation, and information to
enable reservoir navigation.
Features
Benefits
Ability to be deployed in high-temperature
environment
Reliable drilling technologies withstand
excessive temperature and reduces the risk of
failure downhole
Automated steering mechanism that creates a
continuous steer force
Eliminates the need of correction runs, or the
sliding time associated with mud motors
Near-bit-inclination in the steering unit and
vibration sensors in the MWD unit
Improves reservoir navigation with precise
target intersections for longer BHA runs with
complete control of drilling dysfunctions
Steering mechanism independent of hydraulic
parameters such as flow rate, mud weight,
and mud properties
Reduces total time on well by optimizing
hydraulic parameters for improving rate of
penetration
Compatibility with the Baker Hughes large and
diverse fleet of high-power mud motors.
Improves rate of penetration by minimizing
drilling dysfunctions.
Real-time reservoir navigation
Accurate well placement and increased net
pay
Azimuthal gamma ray measurement
Confirmation of bed boundaries and
orientation
Reliable, 2-way communication between
downhole and surface
Real-time decision making and drilling
optimization
High-frequency phase resistivity
Superior vertical resolution and identification
of thin beds and fluid contacts
Low-frequency attenuation resistivity
Increased depth of investigation and accurate
prediction of Rt with greater immunity to
borehole conditions
6-3/4-in. AutoTrak G3 HT-175 RCLS
©2013-2013 Baker Hughes Incorporated. All rights reserved.
ATK3.0-70-01-006 Rev. A
Technical Data S ummary
6-3/4-in. AutoTrak G3 HT-175 RCLS
General Tool Specifications
Borehole Size
Build Rate
Length / Weight
Total
Steering Unit Module
MWD/LWD Module
Power and Comm Module + Stop Sub
Flex Sub Module
Stabilizer Module
Primary Power Source
Connections UP / Down
8-3/8 in. to 8-3/4 in.
9-1/2 in. to 10-5/8 in.
Operating Specifications and Limits
US Units
SI Units
8-3/8 in. to 10-5/8 in. 213 mm to 270 mm
0–6.5°/100 ft
0–6.5°/30 m
49.9 ft / 5,600 lb
15.2 m / 2,540 kg
7.2 ft / 905 lb
2.2 m / 410 kg
17.0 ft / 2,205 lb
5.2 m / 1,000 kg
13.2 ft / 1,290 lb
4.0 m / 585 kg
8.2 ft / 640 lb
2.5 m / 290 kg
4.3 ft / 560 lb
1.3 m / 255 kg
Drilling fluid driven Turbine
NC50 Box / 4-1/2-in. API Reg. Box
NC50 Box / 6-5/8-in. API Reg. Box
US Units
SI Units
Flow Rate
Extreme Low Flow
Low Flow
Medium Flow
Normal Flow
High Flow
gpm
lpm
200 (240)–325
757 (908)–1,230
265 (320)–450
1,000 (1,211)–1,703
330 (395)–570
1,249 (1,495)–2,157
375 (450)–660
1,419 (1,703)–2,498
500 (600)–900
1,893 (2,271)–3,407
()—minimum flow rate for Downlink Operation
Maximum WOB
57,000 lb
255 kN
Maximum Tool Rotation
400 rpm
RPM specification may be reduced depending on Circulating Temperature, Mud
Properties and Well bore Geometry. Please contact Baker Hughes representative for
specific applications.
Maximum Drilling Torque (at the Bit)
22,125 ft-lb
30 kNm
Maximum Torque to Failure (at the Bit)
28,000 ft-lb
38 kNm
Maximum Overpull with Rotation
191,000 lb
850 kN
(Continued Operation)
Maximum Overpull without Rotation
191,000 lb
850 kN
(Continued Operation)
Maximum Overpull to Failure without
697,000 lb
3,100 kN
Rotation
Maximum Tensile Load
697,000 lb
3,100 kN
Maximum Operating Temperature
347°F
175°C
Minimum Operating Temperature
-4°F
-20°C
Maximum Hydrostatic Pressure
30,000 psi
2,070 bar
Maximum Bit Pressure Drop
No Limitation
1% max. volume, acc. to API 13B
Sand Content
(<0.5% recommended)
40 ppb = 114 kg/m³ (Any pumping of LCM
Maximum LCM
must be carried out according to AutoTrak G3
operations manual)
Max DLS for Tool Passage for AutoTrak
With Rotation
13°/100 ft
13°/30 m
Without Rotation
20°/100 ft
20°/30 m
Max DLS for tool passage should only be used as a guide. Actual limits may vary
depending on BHA configuration. Please contact Baker Hughes representative for
specific applications.
±50% Maximum deviation from mean rpm
(e.g. 100 rpm: rpm Range=50–150),
Maximum rpm Variation
limited by max tool rotation specification,
(from recorded memory or as flagged by
corresponding real-time severity level)
Refer to Supplemental Technical
Maximum Axial and Lateral Vibration
Specification document
TDS-20-60-0000-00
Drilling & Evaluation
2001 Rankin Road
Houston, Texas 77073
Phone: +1 713-625-4200
www.bakerhughes.com
Sensor Specifications
US Units
MPR™
2 MHz Propagation Resistivity
Phase Difference (Long Spaced)
Range
0.1–3,000 ohm-m
±1% (0.1–50 ohm-m)
±0.5 mmho/m (>50 ohm-m)
Accuracy
Attenuation
Range
Accuracy
Vertical Resolution
SI Units
0.1–500 ohm-m
±2% (0.1–25 ohm-m)
±1 mmho/m (>25 ohm-m)
8 in. (20 cm) for 90% response in
conductive beds
Azimuthal Gamma Ray
Sensor Type
Measurement
Range
Accuracy
Scintillation (x2)
API GR
0–500 API
±2.5 [email protected] API and
ROP=60 ft/hr (18.3 m/hr)
6 in.
15.3 cm
Vertical Resolution
Directional
Sensor Type
Tri-axial Accelerometer/Tri-axial Flux Gate
MTF/GTF switching
Operator selectable (default: 3°)
Measurement
Range
Resolution
Accuracy1
Inclination
0°–180°
0.09°
±0.1°
Azimith2,3
0°–360°
0.35°
±1.0°
Toolface
Magnetic2 TF
0°–360°
1.4°
±1.5°
Gravity3 TF
0°–360°
1.4°
±1.5°
Total Magnetic Field
0–100,000 nT
35
±100
Dip Angle2
-90°–90°
0.04°
±0.2°
Near Bit Inclination
Sensor Type
Tri-axial Accelerometer
Measurement
Range
Resolution
Accuracy
Inclination
0°–180°
0.09°
±0.1°
Pressure (Annular, Bore & Flow Off Pressure)
Range
0–30,000 psi
0–2,070 bar
Accuracy / Resolution
±0.25% of full scale/5 psi
Vibration
Sensor
Axial Vibration
One Accelerometer, z direction
Type
Lateral Vibration
Two Accelerometers, x-y direction
Acceleration Range
0–15 g
Frequency Range
0–82 Hz
Lateral and Axial vibration; transmitted as
Real-time log options
severity level (scaled to g-RMS)
Average and maximum lateral and axial
Post Run/Memory log options
vibration in g-RMS and as severity level
Rotation and Stick-Slip
Sensor Type
Two Axis Magnetometer
Rotation Speed
0–±1,000 rpm (±1% Accuracy)
Downhole rpm, stick-slip transmitted as
Real-time log options
severity level
Min., Max., and average rpm, stick-slip
Post Run/Memory log options
and backward rotation severity
All Sensor accuracies are 2 Sigma confidence
For a typical magnetic field value at 30° latitude
3 Accuracy applies to inclinations greater than 5.0°
1
2
Although the information contained herein is believed to be accurate, no other representations are made concerning the information. Under no circumstances shall Baker Hughes be liable for any incorrect or incomplete
information. All technical specifications and commercial information concerning the product and/or services described herein may be changed at any time without further notice. Refer to Supplemental Technical Specifications
(TDS-20-60-0000-00) for further environmental specific specifications and information on the application, operation, and handling of Baker Hughes tools. Technical Data Summaries are controlled documents and can only be
released through the Documentation & Records Management System(s) Group.
ATK3.0-70-01-006