6-3/4-in. AutoTrak G3 HT
Transcription
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 API@100 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