2015 Wireline Services Catalog

Wireline Services Catalog The services in this catalog are grouped by their applications. Each service is briefly described and its measurement and mechanical specifications listed. For more information, contact your Schlumberger representative. Links are provided on each page to ease navigation. The PDF may also be browsed normally. From the Contents pages, any of the listed items may be accessed by clicking either the entry or page number. This eBook is also bookmarked. Click here for the table of contents. For help using Adobe Acrobat Reader, press the F1 key or click here to access Adobe Acrobat online help. For optimal viewing of this document, it is recommended that you install the latest version of Acrobat Reader software. Click the icon to download the appropriate version: *Mark of Schlumberger © 2015 Schlumberger. All rights reserved. Other company, product, and service names are the properties of their respective owners.

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Schlumberger 3750 Briarpark Drive Houston, Texas 77042 slb.com Copyright © 2015 Schlumberger. All rights reserved. No part of this book may be reproduced, stored in a retrieval system, or transcribed in any form or by any means, electronic or mechanical, including photocopying and recording, without the prior written permission of the publisher. While the information presented herein is believed to be accurate, it is provided “as is” without express or implied warranty. Specifications are current at the time of printing. Temperature ratings are for the internal tool components. 14-FE-0074 An asterisk (*) is used throughout this document to denote a mark of Schlumberger. Other company, product, and service names are the properties of their respective owners. Cover photograph of the Discoverer Enterprise courtesy of Transocean.

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Contents Introduction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1 Introduction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3

Wireline Services Catalog

Health, Safety, and the Environment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Health, Safety, and the Environment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . HSE Management System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . HSE Policy Statement . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

5 7 7 8

Surface Systems . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Surface acquisition and imaging systems . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Data delivery . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . InterACT* global connectivity, collaboration, and information service . . . . . . . . . . . Data formats . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Telemetry systems . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Field units . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Optimum Service Land Carrier . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Universal Payload Medium Service Land Carrier . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 18,000- and 26,000-lbf offshore units . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Wireline high-tension conveyance systems . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Integrated wireline conveyance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Well Conveyance Planner . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Conveyance in the hostile conditions of high pressure and high temperature . . . . Strengthening cable capabilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Improving surface equipment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Enhancing telemetry and downhole tool power . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . TuffLINE* torque-balanced composite wireline cable . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . UltraTRAC* and UltraTRAC Mono* all-terrain wireline tractors . . . . . . . . . . . . . . . . . . . . . . . . TuffTRAC* and TuffTRAC Mono* cased hole services tractors . . . . . . . . . . . . . . . . . . . . . . . . . . MaxTRAC* downhole wireline tractor . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Drillpipe-assisted wireline deployment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . LWF* logging-while-fishing service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . TLC* tough logging conditions system . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Depth measurement . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

9 11 12 12 12 13 14 14 14 14 16 16 16 17 17 17 18 19 20 22 23 24 24 24 25

Logging Platforms and Suites . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Scanner Family* rock and fluid characterization services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Openhole Scanner services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Cased hole Scanner services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Platform Express* integrated wireline logging tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ThruBit* through-the-bit logging services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Multi Express* slim multiconveyance formation evaluation platform . . . . . . . . . . . . . . . . . . . Xtreme* HPHT well logging platform . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . SlimXtreme* slimhole HPHT well logging platform . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . IPL* integrated porosity lithology service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ABC* analysis behind casing services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Carbonate Advisor* petrophysics and productivity analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . DecisionXpress* petrophysical evaluation system . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . DeepLook-EM* crosswell electromagnetic imaging service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . PS Platform* production services platform . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

27 29 29 30 34 36 39 42 45 47 49 52 53 54 56

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Dielectric Dispersion Logging . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 59 Dielectric Scanner* multifrequency dielectric dispersion service . . . . . . . . . . . . . . . . . . . . . . . 61 Resistivity Logging . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Rt Scanner* triaxial induction service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Induction tools . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . AIT* array induction imager tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Platform Express array induction imager tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Hostile Environment Induction Imager Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . SlimXtreme Array Induction Imager Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Laterolog tools . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ARI* azimuthal resistivity imager . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . HRLA* high-resolution laterolog array tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . High-Resolution Azimuthal Laterolog Sonde . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Microresistivity tools . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . MicroSFL* spherically focused resistivity tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Micro-Cylindrically Focused Log . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Powered Caliper Device with microlog tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . CHFR-Plus* and CHFR-Slim* cased hole formation resistivity tools . . . . . . . . . . . . . . . . . . . .

63 65 67 67 67 67 67 69 69 69 69 71 71 71 71 73

Nuclear Measurements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Gamma ray tools . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Spectral gamma ray tools . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . NGS* natural gamma ray spectrometry tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Hostile Environment Natural Gamma Ray Sonde . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Litho Scanner* high-definition spectroscopy service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ECS* elemental capture spectroscopy sonde . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Neutron porosity tools . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . CNL* compensated neutron logging tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Highly Integrated Gamma Ray Neutron Sonde . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . SlimXtreme Compensated Neutron Porosity Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . CHFP* cased hole formation porosity service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Array Porosity Measurements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . APS* accelerator porosity sonde . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Hostile Environment Accelerator Porosity Sonde . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . RSTPro* reservoir saturation tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Density tools . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Three-Detector Lithology Density . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Litho-Density* Sonde . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Hostile Environment Lithology Density Sonde . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . SlimXtreme Litho-Density Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

75 77 79 79 79 81 83 85 85 85 85 85 87 87 87 89 91 91 92 92 92

Nuclear Magnetic Resonance Logging . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 95 MR Scanner* expert magnetic resonance service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 97 CMR-Plus* combinable magnetic resonance tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 99 Acoustic Logging . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 101 Sonic Scanner* acoustic scanning platform . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 103 ThruBit Dipole* through-the-bit acoustic service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 105 DSI* dipole shear sonic imager . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 107 Monopole acoustic tools . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 109 Digital Sonic Logging Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 109 SlimXtreme Sonic Logging Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 109

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Dipmeter and Imaging Services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 111 Quanta Geo* photorealistic reservoir geology service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 113 FMI-HD* high-definition formation microimager . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 116 FMI* fullbore formation microimager . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 118 UBI* ultrasonic borehole imager . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 120 OBMI* oil-base microimager . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 122 Drilling and Directional Services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 125 GPIT general purpose inclinometry tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 127 Seismic Imaging Tools and Services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 129 Q-Borehole* integrated borehole seismic system . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 131 VSI* versatile seismic imager . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 131 SWINGS* seismic navigation and positioning system . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 133 TRISOR* acoustic source control element . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 134 Q-Borehole integrated borehole seismic system . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 135 DeepLook-CS* crosswell seismic imaging service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 136 CSI* combinable seismic imager . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 138 Q-Borehole Explorer* high-output, wide-bandwidth truck vibrator . . . . . . . . . . . . . . . . . . . . . . . . 140 Other land seismic sources . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 140 Marine seismic sources . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 142 Formation Testing and Sampling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 143 MDT Forte* and MDT Forte-HT* rugged and high-temperature modular formation dynamics testers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 145 MDT* modular formation dynamics tester . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 147 Saturn* 3D radial probe . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 149 Quicksilver Probe* focused fluid extraction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 151 InSitu Fluid Analyzer* real-time downhole fluid analysis system . . . . . . . . . . . . . . . . . . . . . . . . 153 InSitu Composition* and InSitu CO2* sensors . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 153 InSitu GOR* sensor . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 153 InSitu Color* sensor . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 153 InSitu Density* sensor . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 153 InSitu Viscosity* sensor . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 153 InSitu Fluorescence* sensor . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 153 InSitu pH* sensor . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 153 InSitu Resistivity* sensor . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 154 Pressure and temperature sensors . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 154 Fluid profiling characterization of reservoir fluid properties variation . . . . . . . . . . . 154 InSitu Pro* real-time quality control and interpretation software . . . . . . . . . . . . . . . . . . . . . . . 156 Advanced MDT tester modules . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 157 Dual-Packer Module . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 157 Dual-Probe Module . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 159 Flow-Control Module . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 160 Pumpout Module . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 161 LFA* live fluid analyzer . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 162 CFA* composition fluid analyzer . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 163 MDT tester low-shock sampling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 164 MDT tester Multisample Module . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 165

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PressureXpress-HT* high-temperature reservoir pressure service . . . . . . . . . . . . . . . . . . . . . . . 166 PressureXpress* reservoir pressure while logging service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 168 SRFT* slimhole repeat formation tester . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 170 CHDT* cased hole dynamics tester . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 172 XL-Rock* large-volume rotary sidewall coring service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 174 MSCT* mechanical sidewall coring tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 176 CST* chronological sample taker . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 177 Well Integrity Evaluation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 179 Isolation Scanner* cement evaluation service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 181 Cement bond logging tools . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 183 SlimXtreme Sonic Logging Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 183 Cement bond log from Digital Sonic Logging Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 183 Cement bond log from Hostile Environment Sonic Logging Tool . . . . . . . . . . . . . . . . . . 184 Slim Cement Mapping Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 184 Memory Slim Cement Bond Logging Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 184 USI* ultrasonic imager . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 185 EM Pipe Scanner* electromagnetic casing inspection tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 187 Corrosion monitoring . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 189 UCI* ultrasonic casing imager . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 189 PS Platform Multifinger Imaging Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 191 Production Logging Services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 193 Flow Scanner* horizontal and deviated well production logging system . . . . . . . . . . . . . . . . 195 PS Platform production services platform . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 197 RSTPro reservoir saturation tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 200 WFL* water flow log from the RSTPro reservoir saturation tool . . . . . . . . . . . . . . . . . . . 200 RSTPro tool with silica activation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 201 CPLT* combinable production logging tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 202 Combinable Gamma Ray Sonde . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 203 Phase Velocity Sonde . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 204 FloView* holdup measurement tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 206 Multiple-Isotope Spectroscopy Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 207 Perforating Services and Accessories . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 209 SPAN Rock* stressed rock perforating analysis and Schlumberger premium charges . . 211 PowerJet Nova* extradeep penetrating shaped charges . . . . . . . . . . . . . . . . . . . . . . . . . . . 211 PowerJet Omega* deep penetrating perforating shaped charge . . . . . . . . . . . . . . . . . . 212 PFrac Nova* perforating charge for optimizing stimulation treatment . . . . . . . . . . . 212 PowerFlow* slug-free big hole shaped charge . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 212 Perforating explosives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 213 Gun systems and charges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 214 Capsule gun systems . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 214 Enerjet* expendable strip gun system . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 214 Pivot Gun* through-tubing perforating gun system . . . . . . . . . . . . . . . . . . . . . . . . . . 214 PowerSpiral* spiral-phased capsule perforating system . . . . . . . . . . . . . . . . . . . . . 215 Hollow carrier perforating gun systems . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 216 HSD* high shot density perforating gun system . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 216 Fractal* multistage stimulation perforating system . . . . . . . . . . . . . . . . . . . . . . . . . 216 Frac Gun multistage fracture stimulation perforating gun system . . . . . . . . . . 216

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PURE* clean perforations system . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 219 Detonation systems . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 221 Secure2* RF-safe electronic detonator . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 221 S.A.F.E.* slapper-actuated firing equipment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 221 ASFS* addressable-switch firing system . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 222 Perforating accessories . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 223 Casing collar locator . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 223 UPCT* universal perforating and correlation tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 224 PGGT* powered gun gamma tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 225 WPP* wireline perforating platform . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 226 Wireline Oriented Perforating Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 228 Through-tubing perforating positioning devices . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 229 Magnetic Positioning Device . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 229 Spring Positioning Device . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 229 Wireline Perforating Anchor Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 230 Cutters and colliding tools . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 231 PowerCutter* precision tubular cutter . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 231 Punchers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 232 Well Intervention Services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 233 ReSOLVE* instrumented wireline intervention service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 235 High-force linear actuator tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 235 Selective universal shifting tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 236 Nonexplosive setting tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 236 Milling tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 236 Casing Packer Setting Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 238 Gauge ring and junk basket . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 239 PosiSet* mechanical plugback tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 240 Auxiliary Measurements and Devices . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 243 Caliper log . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 245 Auxiliary Compression Tension Sub . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 246 Environmental Measurement Sonde . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 247 FPIT* free-point indicator tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 249 CERT* correlated electromagnetic retrieval tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 250

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Introduction

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Introduction During the early 1900s Conrad and Marcel Schlumberger experimented with surface electrical measurements as a way of defining the Earth’s subsurface structure. In 1927 they performed their experiment in an oil well in France for the Pechelbronn Oil Company. The result was the first electrical log, and it showed conclusively that geologic formations penetrated by the drill could be identified by electrical measurements. The electric log gave eyes to the oil finders, who previously could rely only on drill cuttings and core samples. In the years since that historic event in France, Schlumberger has become the world’s leading supplier of technology, integrated project management, and information solutions to customers working in the oil and gas industry worldwide. Employing approximately 123,000 people representing over 140 nationalities and working in more than 85 countries, Schlumberger provides the industry’s widest range of products and services from exploration through production. Schlumberger is organized as an integrated oilfield services company in GeoMarket* regions that provide customers with a single point of contact at the local level for field operations and bring together geographically focused teams to meet local needs and deliver customized solutions. Working together

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with the company’s 15 product lines, the GeoMarket regions provide a powerful conduit through which information and know-how flow to the customers, and through which Schlumberger engineers and geoscientists maximize technological synergies over the entire life of the field. The importance of the timely flow of information is especially true in the oil and gas industry, where critical decisions hinge upon the availability of data. Data acquired by Schlumberger is made available to operators in real time by using the Internet and satellite communication networks. Decisions made on the basis of these data can be implemented quickly and efficiently. As wells proliferate in deeper water depths with attendant high pressures and high temperatures, the operating envelope of logging tools is also being expanded to provide the same reliable performance and high-quality data as in conventional wells. Similarly, well geometries are becoming increasingly complex. To meet this challenge, most logging tools in use today can be conveyed on drillpipe, coiled tubing, or wireline tractors to address a wide range of well conditions. Oil fields around the world are aging, driving an increasing need to evaluate old wells. Schlumberger provides stateof-the-art formation evaluation services

in cased wells, including measurements that until recently were available only in openhole environments. On a larger scale, efficient decision making for full-field enhanced oil recovery (EOR) projects progresses from measurements for determining feasibility to pilot projects for understanding the complex interaction of injected agents with existing reservoir fluids in the everchanging downhole environment. Production logging, cement and corrosion evaluation, and nuclear measurements made after casing has been set are increasingly used to identify problems and monitor well performance. The comprehensive Schlumberger line of production services is engineered for safety, reliability, and performance. New perforation systems have also been developed with a focus on maximizing production by engineering shaped charges to shoot deeper in stressed rock at downhole pressures and temperatures. The services in this catalog are grouped according to their applications. A brief description of each service and its measurement and mechanical specifications are included. For more information on designing a logging program to meet your specific needs, contact your Schlumberger representative.

Introduction

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Health, Safety, and the Environment

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Health, Safety, and the Environment Schlumberger has a long-standing HSE commitment to the highest standards for the health and safety of our employees, customers, and contractors as well as to the protection of the environment in the communities in which we live and work.

HSE Management System The Schlumberger HSE Management System defines the principles by which we conduct our operations worldwide with regards to health, safety, and the environment. Management communicates the HSE philosophy to all employees, customers, contractors, and third parties associated with our business, and each Schlumberger organization must provide positive evidence of conformance to the system.

The HSE Management System model comprises eight interrelated components: ■ commitment and leadership and accountability ■ policies and objectives ■ organization and resources ■ contractor and supplier management ■ risk management ■ business processes ■ performance monitoring and improvement ■ audits and reviews.

These are continuously improved by conformance checks ■ on day-to-day standards and procedures (controls) ■ on the management system (correction) ■ through modifications to the management system (improvement).

Commitment and Leadership and Accountability

Improvement

Policies and Objectives

Organization and Resources

Contractor and Supplier Management Corrections Risk Management

Business Processes

Performance Monitoring and Improvement

Controls

Audits and Reviews

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Health, Safety, and the Environment

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HSE Policy Statement Statement from Paal Kibsgaard, Schlumberger Chief Executive Officer The long-term business success of Schlumberger depends on our ability to continually improve the quality of our services and products while protecting people and the environment. Emphasis must be placed on ensuring human health, operational safety, environmental protection, quality enhancement, and community goodwill. This commitment is in the best interests of our customers, our employees and contractors, our stockholders, and the communities in which we live and work. Schlumberger requires the active commitment to, and accountability for, QHSE from all employees and contractors. Line management has a leadership role in the communication and implementation of, and ensuring compliance with, QHSE policies and standards. We are committed to ■ Protect, and strive for improvement of, the health, safety and security of our people at all times; ■ Eliminate Quality non-conformances and HSE accidents; ■ Meet specified customer requirements and ensure continuous customer satisfaction; ■ Set Quality & HSE performance objectives, measure results, assess and continually improve processes, services and product quality, through the use of an effective management system; ■ Plan for, respond to and recover from any emergency, crisis and business disruption; ■ Minimize our impact on the environment through pollution prevention, reduction of natural resource consumption and emissions, and the reduction and recycling of waste; ■ Apply our technical skills to all HSE aspects in the design and engineering of our services and products; ■ Communicate openly with stakeholders and ensure an understanding of our QHSE policies, standards, programs and performance. Reward outstanding QHSE performance; ■ Improve our performance on issues relevant to our stakeholders that are of global concern and on which we can have an impact, and share with them our knowledge of successful QHSE programs and initiatives. This Policy shall be regularly reviewed to ensure ongoing suitability. The commitments listed are in addition to our basic obligation to comply with Schlumberger standards, as well as all applicable laws and regulations where we operate. This is critical to our business success because it allows us to systematically minimize all losses and adds value for all our stakeholders. Paal Kibsgaard Chief Executive Officer Last Update on 14 December 2011

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Surface Systems

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Surface Acquisition and Imaging Systems All Schlumberger new-generation wireline logging units are equipped with the Enhanced Wireline Acquisition Front-End (eWAFE). The eWAFE system’s modular, versatile, and fully redundant architecture improves on the predecessor MAXIS* multitask acquisition and imaging system to enable combining and conveying the latest and most complex array of sensors in the Schlumberger portfolio. Under the full configuration, eight programmable, high-density universal power modules (UPMs) can simultaneously supply several types of power (AC, DC, EMEX,

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and three-phase AC) at more than 3 times the output power of the MAXIS system. In the event of a modular unit failure, the field engineer can switch to the built-in backup module with minimum downtime. The eWAFE system interfaces downhole tools with the high-end acquisition and data-recording processors of the Modular Configuration MAXIS system (MCM) through MaxWell* integrated field acquisition software. MaxWell software provides data acquisition and tool control functionality, real-time playback capabilities, wellsite answer solutions

comparable to those from a processing center, and real-time data transmission via satellite or the communications module built into the eWAFE system. In combination with InterACT* global connectivity, collaboration, and information service, the eWAFE system securely delivers real-time log data from remote sites to support timely decision making concerning the reservoir and well.

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Data Delivery Schlumberger recognizes that the data gathered in the field must be transferred to the users as reliably and as quickly as possible. To this end, Schlumberger has a proven global data delivery network that securely, reliably, and efficiently transfers data from remote sites. Data can be transmitted from the wellsite and forwarded via e-mail, facsimile, and File Transfer Protocol (FTP). Schlumberger InterACT global connectivity, collaboration, and information service furthers real-time data accessibility from a Web browser. InterACT service supports ■ transfer of real-time wireline, drilling, and completion data ■ secure, managed sharing of project data with third parties and partners ■ all project data gathered in one location, regardless of who produced them.

InterACT global connectivity, collaboration, and information service InterACT global connectivity, collaboration, and information service is a user-friendly, intuitive system that requires no installation of specialized software. From a connection to either the Internet or a local intranet, data are downloaded or viewed using interactive, customizable graphics viewers on a PC or conveniently on iPhone® and iPad® mobile digital devices by using InterACT service’s app. Real-time data can be automatically and continuously delivered to and viewed on the user’s computer or mobile device.

The wellsite engineer simply uploads graphical or digital data to the InterACT website for remote users to view or analyze in real time. Formats supported include Digital Log Information Standard (DLIS), Log ASCII Standard (LAS), and American Standard Code for Information Interchange (ASCII) for digital data and Picture Description System (PDS), Tagged Image File Format (TIFF), or many other file types for graphical data. The embedded log graphics viewer provides options to view and manipulate wireline data. For example, wireline and drilling data can be viewed concurrently on the same log presentation. During operations such as reservoir sampling, experts at different locations can collaborate on data viewed or interpreted in real time for immediate decision making on critical issues. The most difficult part of data exchange is sending data from a remote site. Because local telecommunication systems in some areas can be unreliable, Schlumberger uses proprietary transfer protocols to ensure robust data transfer. Encrypted data are compressed for efficiency, and automatic link recovery is available if telecommunications breaks occur. This superior transfer process means that InterACT service can be used even in areas with unsophisticated communication links. InterACT service uses best-in-class security standards for both hardware and software. All data transfer uses 128-bit Secure Sockets Layer (SSL) encryption. The system meets industry security standards, minimizing the risk of data disclosure. If an intranet-only solution is preferred, Schlumberger can

install and maintain the system in the customer’s office. The same process used for internal team members easily controls partner access to data. Because the data reside centrally in the system database, there is no need for continual updates and distribution. Partners access specified data at the operator’s discretion.

Data formats MaxWell integrated field acquisition software creates and records three industry formats: ■ DLIS—Created by Schlumberger initially as the Log Information Standard (LIS), DLIS is the industry standard today for all well acquisition data. ■ LAS and ASCII—This reduced dataset is regularly used for interpretation conducted on standard PCs and is compatible with customer-proprietary and commercially available software. ■ Portable document format (PDF)— This file format for electronic images is used for graphical display, manipulation, and printing of data curves and imaging logs. Other limited formats can be generated upon request.

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Telemetry systems The telemetry system provides the interface through which data are delivered from the downhole toolstring to the surface data acquisition and processing system. High-rate telemetry system—The Enhanced Digital Telemetry System (EDTS) uses an enhanced fast tool bus (EFTB) in downhole tools to provide data rates up to 2  Mbps for the uplink rate. EDTS and EFTB Versions 2.0 double the data transmission bandwidth up to 4 Mbps and are backward compatible with all existing EDTS and EFTB systems. This represents a 40% increase in bandwidth compared with the first-generation Cable Telemetry System (CTS). Along with the enhanced wireline hepta

cable (AWG 18 and 16 conductors and new-generation polymer), EDTS 2.0 and EFTB 2.0 use state-of-the-art error detection and correction protocols to ensure highly reliable high-rate data transmission with the lowest error rate on cables exceeding 40,000 ft [12,200 m] in length. Medium-rate telemetry system— The Monocable Telemetry System (MTS) has been specially developed for mono cable or coaxial cable operations in cased hole applications. MTS is a single-channel quadrature amplitude modulation (QAM) link with data speed rates from 10 to 100 Kbps for the uplink rate. MTS comes as a separate downhole cartridge or is incorporated in the hardware of a downhole tool using MTS.

Low-rate telemetry system—The Low-Bandwidth Telemetry System (LTS) is the latest addition to extend bandwidth coverage to very low data rates for certain services. LTS telemetry rates range from a few hundred bits per second up to 10 Kbps. LTS operates in parallel and transparently to the main EDTS and MTS telemetry systems, and the related downhole hardware is incorporated in the downhole tool.

Specifications EDTC-H Telemetry Cartridge Temperature rating

400 degF [204 degC]

Pressure rating

20,000 psi [138 MPa] 30,000 psi [207 MPa]

Outside diameter

3.625 in [9.21 cm]

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Field Units Optimum Service Land Carrier

Universal Payload Medium Service Land Carrier

18,000- and 26,000-lbf offshore units

The Optimum Service Land Carrier (OSLC) is used to perform open- or cased hole logging operations. The design emphasis for this integrated, full-service logging carrier minimizes the overall size of the truck but still provides full cable capacity by allowing the use of existing large-capacity winch drum reels (WDRs). The resulting unit efficiently performs fullservice operations from an inter­ mediate-size vehicle. The OSLC also has excellent off-road capabilities through its 6×4 drive configuration. The cabin layout has both the winch operator and engineer facing the rig. The three versions of the OSLC are equipped with the fully redundant eWAFE acquisition system and can carry a maximum of 28,000 ft [8,500 m] of 7-46 standard cable or 26,500 ft [8,080 m] of high-power, high-tension hepta cable on the WDR-42 drum. ■ OSLC-G is built on the Renault Trucks 6×4 K 380 chassis meeting Euro 5 emissions regulations in Europe or Euro 3 outside Europe and North America. ■ OSLC-H is the equivalent North American truck, compliant with US EPA 2007 and recent 2010 emissions regulations. It is built on the Kenworth 6×4 T800 chassis. ■ OSLC-F is similar to the OSLC-G. Built on the Renault 6×6 K 380 chassis and equipped with Euro  3 engines, its main application is offroad desert operations.

The latest generation Medium Service Land Carrier is the Universal Payload (UPL), which features an eWAFEequipped (upgradable to fully redundant eWAFE configuration) medium service logging cabin that is integrated with various chassis by employing specifically designed subframes. This modular design makes it easy to export the UPL to meet emissions regulations for different locations. The cabin is fitted onsite on a locally available and qualified chassis, which avoids delays from lengthy customs clearance and emissions compliance determination for a fully integrated vehicle. North American integration is conducted in the USA, Southeast Asia (right-hand drive) integration is in Australia, and all others are in France. The UPL replaces the MAXIS Express* Medium Service Land Carrier (MSLC) with similar specifications: 4×4 or 4×2 chassis, 16,000 ft [4,880 m] of standard 7-46 logging cable on the WDR-56 drum, and suitable for most openhole and cased hole operations.

Schlumberger heavy-duty modular offshore skid units are used to deploy standard high-strength cable and TuffLINE* 18000 and 26000 torquebalanced composite wireline cables. The OSU-PA and OSU-PB units using TuffLINE 18000 cable can provide instantaneous pull of up to 18,000 lbf [80,070 N] for stick prevention and mitigation without a capstan. If operating conditions will result in normal logging tension exceeding 13,000  lbf [57,800 N], the OSU-PA or OSU-PB can be interfaced with a capstan to provide up to 21,500-lbf [95,640-N] pull capacity with standard high-strength cable. The OSU-N unit interfaced with the 26,000‑lbf [115,660‑N] capstan and TuffLINE 26000 cable can provide 26,000-lbf pull capacity with more than 43,000 ft [13,100 m] of cable capacity on the drum. The OSU-PB and the MONU-B are CE-marked electrohydraulic units certified for Zone 2 operations.

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Specifications

Modular components

OSU-PA and OSU-PB Offshore Units

MONU-B Offshore Unit

OSU-N Offshore Unit

Power pack module (POSU): • Diesel (OSU-PA) • Electrohydraulic (OSU-PB)

Power pack module (EHPS): • Electrohydraulic

Power pack module (POSU): • Redundant, dual electrohydraulic, base frame mounted

Logging module (COSU): • High-tension cabin

Logging module (ONCC): • Offshore NORSOK-compliant cabin

Logging module (COSU): • Ultradeepwater cabin • High-tension cabin

Winch module (WOSU): • High-tension WOSU with WDR‑59 drum

Winch module (WDDS or WOSU): • Zone‑rated WDDS with WDR-59 drum • High-tension WOSU with WDR-59 drum

Acquisition system

Full-configuration dual eWAFE system

Full-configuration dual eWAFE system

Full-configuration dual eWAFE system

Drum capacity

WDR-59 with TuffLINE 18000 cable: 33,000 ft [10,060 m]

WDR-59 with TuffLINE 18000 cable: 33,000 ft [10,060 m]

WDR-70 with TuffLINE 26000 cable: 43,000 ft [13,100 m] WDR-59 with TuffLINE 18000 cable: 33,000 ft [10,060 m]

Pull capacity without capstan

WOSU: 18,000 lbf [80,070 N]

WDDS: 11,400 lbf [50,710 N] WOSU: 18,000 lbf [80,070 N]

18,000 lbf [80,070 N]

Capstan pull capability

Zone-rated, deck-mounted dual drum (WDDC-BB): 24,000 lbf [106,760 N] ATEX zone-rated, CE-marked, deckor derrick-mounted dual drum (ZPPC): 24,000 lbf [106,760 N]

ATEX zone-rated, CE-marked, deck-  or derrick-mounted dual drum (ZPPC): 24,000 lbf [106,760 N]

Zone-rated, deck-mounted dual drum (WDDC-BC): 26,000 lbf [115,660 N]

Special applications

Single or modular deployment DNV 2.7-1, 2.7-2, 2-22 OSU-PB: CE and ATEX Zone 2

Modular deployment WOSU: DNV 2.7-1, 2.7-2, 2-22 NORSOK and CE Zone 2

Single deployment DNV 2.7-1 Quick-swap winch drum capability

Surface Systems

Winch module (WOSU): • Ultradeepwater WOSU  with WDR-70 drum • High-tension WOSU with WDR-59 drum

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Wireline High-Tension Conveyance Systems Integrated wireline conveyance From conventional well environments to ultradeep and highly deviated wells and where increased pulling power is required, Schlumberger provides efficient and reliable wireline conveyance. The deployment of TuffLINE torque-balanced composite wireline cable on an integrated hightension conveyance system expands wireline data acquisition capabilities with unprecedented improvements in safety, efficiency, reliability, and sticking avoidance, especially for hightension operations. The integration of high-strength cable, heavy-duty modular logging units, an optional capstan package providing complete

This comprehensive planning tool recommends the optimal conveyance system while identifying system components that exceed specifications. The user can modify operational conditions and equipment and also specify customer requirements for the planner to recompute conveyance capabilities. To avoid the operational limitations of mechanical weakpoints and previous-generation ECRDs, a SureLOC cable release device is used. The design can also incorporate a wide range of WellSKATE low-friction conveyance accessories to significantly decrease the risk of differential sticking by rolling instead of sliding to reduce friction coefficients and by keeping the toolstring away from the borehole wall.

tension relief, WellSKATE* low-friction well conveyance accessories, and the SureLOC* electronically controlled cable release device (ECRD) as designed using the Well Conveyance Planner means that well trajectories and conditions that were not previously wireline accessible no longer have to automatically resort to alternative methods of conveyance. As necessary, wireline deployment can be augmented with the use of wireline tractors.

Well Conveyance Planner Reliable conveyance for both routine and high-tension operations begins with calculation of the pulling capabilities and associated operating risk by the Well Conveyance Planner.

Sheave hanger Sheave wheel

TuffLINE cable

Winch drum

Optional capstan

Offshore unit

Tieback sling Weakpoint

Capstan-free pull capability: 18,000 lbf Pull capability with capstan: TuffLINE 26000 cable: 26,000 lbf

SureLOC cable release device

Antisticking accessories

The integrated wireline high-tension conveyance system provides efficient and reliable deployment.

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Specifications SureLOC Cable Release Device Safe working load

SureLOC 8000: 8,000 lbf [35,580 N] SureLOC 12000: 12,000 lbf [53,380 N]

Max. tool-release head tension

At surface: 1,000 lbf [4,450 N]

Temperature rating

SureLOC 8000: 400 degF [204 degC] SureLOC 12000: 500 degF [260 degC] SureLOC 8000: 20,000 psi [138 MPa] SureLOC 12000: 30,000 psi [207 MPa] SureLOC 12000: MP35N® H₂S-resistant alloy

Pressure rating Special applications

Conveyance in the hostile conditions of high pressure and high temperature

Strengthening cable capabilities When ultradeep wells are logged, their pressure and temperature are not the only concerns: extreme depths limit conventional high-strength wireline conveyance because of the high surface tension that results from increased drag and the weight of the logging cable itself. Deploying logging tools on drillpipe using the TLC* tough logging conditions system can overcome these limitations, but TLC operations take more time and cost more because of the reduced efficiency associated with tripping drillpipe. To solve the ultradeep well dilemma, TuffLINE 18000 and 26000 composite cables were developed as the central element of the integrated wireline high-tension conveyance system. From the cable through the surface equipment, the system provides a complete conveyance solution for every possible extreme well

Wireline formation evaluation technology and its conveyance are put to the test when logging deep wells. As wells get deeper, the pressure and temperature rise, which increases the risks associated with deployment and operation. Wells with static bottomhole temperatures greater than 302 degF [150 degC], bottomhole pressures higher than 20,000 psi [138 MPa], or both conditions are generally regarded as high pressure, high temperature (HPHT). However, despite the increased risks and costs of HPHT operations, the number of deep and ultradeep wells drilled continues to grow worldwide. The challenges that the depths, pressures, and temperatures of these wells present to formation evaluation are met by the following significant technological developments in conveyance. 650

High temperature High pressure

550 Reservoir temperature, degF

450 350 250 Conventional

150

0

5,000

10,000

15,000

20,000

25,000

30,000

Reservoir pressure, psi Global HPHT conditions pose challenges for wireline deployment and operations.

35,000

environment: HPHT, ultradeepwater, extended-reach, and complex trajectory wells. The efficiency gains resulting from wireline logging of ultradeep wells by using the integrated conveyance system translate to significant cost savings for the operator. TuffLINE torque-balanced composite wireline cable employs the breakthrough technology of polymer-locked armors to effectively overcome the fundamental limitations of conventional armored cables. The result is not just high-strength capability, but also unprecedented improvements in safety. TuffLINE 26000 cable is the industry’s highest-strength cable, with a safe working load (SWL) of 26,000 lbf [115,650 N] and an ends-free breaking strength in excess of 40,000 lbf [178,000 N]. Polymer locking of the inner and outer armors balances TuffLINE 18000 cable’s torque in a consistent low state. With only negligible torque buildup possible, birdcaging and premature cable breakage are prevented. TuffLINE 18000 cable also incorporates a unique polymer-reinforced crush-resistant core.

Improving surface equipment Improved surface equipment is another critical component of the integrated conveyance system for deploying TuffLINE 18000 and 26000 cables at high tension and in HPHT conditions. Operations with continuous logging tensions of 13,000 lbf [57,800 N] or lower can deploy TuffLINE cable using a Schlumberger modular heavyduty offshore unit without involving a capstan, which significantly reduces risk. When logging tension exceeds 13,000 lbf or maximum pull tension in excess of 18,000 lbf [80,070 N] is required, an optional dual-drum capstan can be employed. The dualdrum capstan is a powered multisheave conveyance system that is placed between the well and the logging unit to decrease the cable tension below the cable-crushing tension of 8,000  lbf [35,580  N] before the cable

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is spooled onto the storage drum. Full integration of capstan control with the storage drum provides a safer, seamless operation and enables the winch operator to focus on the well conditions. The specially designed high-tension dual-drum system conveying TuffLINE  26000 cable can safely sustain 26,000-lbf tension in the well at conveyance speeds to 15,000 ft/h [4,570 m/h].

Enhancing telemetry and downhole tool power The extralong cables required for ultradeep well logging must be capable of transmitting sufficient power downhole to run high-power, complex toolstrings while enabling seamless transmission of increasingly larger

amounts of data uphole to the surface. Because of physical limitations, data transmission telemetry systems have proved to be unreliable at extreme well depths. When long cables are run in deep wells, the amount of power and telemetry bandwidth available at the tool end is limited by the cable conductor line resistance. Increasing the well temperature raises the line resistance and adversely affects cable transmission characteristics, further limiting power and telemetry transmission. Unlike standard high-strength cables, TuffLINE 18000 cable has 18  AWG gauge conductors and TuffLINE 26000 cable has industryleading 16  AWG gauge conductors enabling reliable conveyance of tool combinations longer than 175  ft [53  m] and at 4,000-lbf [17,790‑N] weight in well depths exceeding

40,000 ft [12,190 m]. Combining tools reduces the number of descents in the well, saving an average of 12 h or more per trip on a deepwater rig. Complementing TuffLINE cable’s high-capacity electrical power and telemetry capabilities, the OSU-PA and OSU-PB surface units are Det Norske Veritas (DNV) 2.22 certified to pull to 18,000 lbf. The OSU-N unit combined with the high-tension dual-drum capstan system can store 43,000 ft [13,100  m] of TuffLINE 26000 cable and sustain 26,000-lbf tension. All these high-tension heavy-duty units are equipped with the highly integrated Enhanced Wireline Acquisition FrontEnd (eWAFE) acquisition system to provide full redundancy, increased power, and enhanced telemetry for deploying large, seamless tool combinations in ultradeep wells.

Specifications

Modular components

OSU-PA and OSU-PB Offshore Units

MONU-B Offshore Unit

OSU-N Offshore Unit

Power pack module (POSU): • Diesel (OSU-PA) • Electrohydraulic (OSU-PB)

Power pack module (EHPS): • Electrohydraulic

Power pack module (POSU): • Redundant, dual electrohydraulic, base frame mounted

Logging module (COSU): • High-tension cabin

Logging module (ONCC): • Offshore NORSOK-compliant cabin

Logging module (COSU): • Ultradeepwater cabin • High-tension cabin

Winch module (WOSU): • High-tension WOSU with WDR‑59 drum

Winch module (WDDS or WOSU): • Zone‑rated WDDS with WDR-59 drum • High-tension WOSU with WDR-59 drum

Acquisition system

Full-configuration dual eWAFE system

Full-configuration dual eWAFE system

Full-configuration dual eWAFE system

Drum capacity

WDR-59 with TuffLINE 18000 cable: 33,000 ft [10,060 m]

WDR-59 with TuffLINE 18000 cable: 33,000 ft [10,060 m]

WDR-70 with TuffLINE 26000 cable: 43,000 ft [13,100 m] WDR-59 with TuffLINE 18000 cable: 33,000 ft [10,060 m]

Pull capacity without capstan

WOSU: 18,000 lbf [80,070 N]

WDDS: 11,400 lbf [50,710 N] WOSU: 18,000 lbf [80,070 N]

18,000 lbf [80,070 N]

Capstan pull capability

Zone-rated, deck-mounted dual drum (WDDC-BB): 24,000 lbf [106,760 N] ATEX zone-rated, CE-marked, deckor derrick-mounted dual drum (ZPPC): 24,000 lbf [106,760 N]

ATEX zone-rated, CE-marked, deck-  or derrick-mounted dual drum (ZPPC): 24,000 lbf [106,760 N]

Zone-rated, deck-mounted dual drum (WDDC-BC): 26,000 lbf [115,660 N]

Special applications

Single or modular deployment DNV 2.7-1, 2.7-2, 2-22 OSU-PB: CE and ATEX Zone 2

Modular deployment WOSU: DNV 2.7-1, 2.7-2, 2-22 NORSOK and CE Zone 2

Single deployment DNV 2.7-1 Quick-swap winch drum capability

Winch module (WOSU): • Ultradeepwater WOSU  with WDR-70 drum • High-tension WOSU with WDR-59 drum

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TuffLINE Torque-Balanced Composite Wireline Cable With high-strength capability, cable conveyance remains the most costeffective method for deploying tools in and out of wells. For increasing well depths, trajectory complexity, and toolstring weight, Schlumberger has developed TuffLINE 18000 and 26000 ultrastrength wireline cables for operations with up to 18,000  lbf [80,070‑N] and 26,000‑lbf [115,650‑N] tension, respectively. TuffLINE 18000 and 26000 composite cables employ the breakthrough technology of polymer-locked armors to overcome the fundamental limitations of current armored cables. Polymer locking of both the inner and outer armors means that the cable is torque balanced, remaining in a consistent state of low torque to prevent birdcaging and premature cable breakage. Polymer locking of the armors prevents rotation to effectively maintain TuffLINE

cable in a permanent ends-fixed situation, which raises the ends-free breaking strength safety margins to an unprecedented 9,000 lbf [40,000 N] for TuffLINE 18000 cable and 10,000 lbf [44,450 N] for TuffLINE  26000 cable above the safe working load. The multilayered core of TuffLINE 18000 cable is crushproof. Cold flow and the permanent deformation it causes are further prevented by the polymer locking of the armors. Spooling tensions to 13,000 lbf [57,800  N] and instantaneous pull to 18,000 lbf are possible for TuffLINE 18000 cable without requiring use of a tensionrelief capstan or having to resort to time-consuming pipe-conveyed operations. TuffLINE 26000 cable can be spooled at any tension up to 26,000 lbf because it is deployed with a capstan.

Incorporation of 18 AWG gauge connectors in TuffLINE 18000 cable and AWG 16 gauge connectors in TuffLINE  26000 cable enables the reliable conveyance of significantly larger, seamless tool combinations in deeper wells.

Applications Deepwater and ultradeepwater wells ■ Extended-reach and complex trajectory wells ■ Deepwater wells with rig-up constraints for capstan operations ■ Reservoir sampling and pressure measurement involving long station times with long and heavy toolstrings ■

Specifications TuffLINE 18000 Cable

TuffLINE 26000 Cable

Ends-fixed breaking strength

28,000 lbf [124,550 N]

>40,000 lbf [>178,000 N]

Ends-free breaking strength

27,000 lbf [120,100 N]

>36,000 lbf [>160,150 N]

Safe working load

18,000 lbf [80,070 N]

26,000 lbf [115,650 N]

Temperature rating

1 h: 465 degF [241 degC] 24 h: 240 degF [232 degC]

1 h: 465 degF [241 degC] 24 h: 240 degF [232 degC]

Cable OD

0.5 in [1.27 cm]

0.535 in [1.36 cm]

Cable weight

In air: 416 lbm/1,000 ft [189 kg/300 m] In freshwater: 331 lbm/1,000 ft [150 kg/300 m]

In air: 524 lbm/1,000 ft [234 kg/300 m] In freshwater: 425 lbm/1,000 ft [190 kg/300 m]

Max. (rms) voltage, V

Per helical conductor: 800 Center conductor: 1,250

Per helical conductor: 780 Center conductor: 1,235

Max. current per conductor, A

1.61

2.6

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UltraTRAC and UltraTRAC Mono All‑Terrain Wireline Tractors Delivering the farthest reach in the industry, the modular UltraTRAC* allterrain wireline tractor provides the highest tractor force available in combination with reverse tractoring capability, dynamic suspension, and traction control. The UltraTRAC Mono* tractor system adds logging-while-tractoring functionality. Although specifically engineered for openhole operations, the UltraTRAC tractor performs with the same reliability in cased hole environments, making it the ideal tractor for conveying most wireline openhole and cased hole services, especially for deployment on TuffLINE 18000 and 26000 torque-balanced composite wireline cables in extended-reach wells and for heavy payloads. The traction force applied by the bidirectional, high-torque UltraTRAC tractor is precisely controlled from the surface. Sensors incorporated in the UltraTRAC tractor enable the engineer to monitor tractor response and the progress of downhole operations as the automatic radial force regulation and dynamic suspension systems continuously configure the tractor in real time for optimal performance. In addition to versatility in the number and configuration of the drive sections, a tandem sub can be added to increase functionality by enabling independent surface control of the drive above the tandem sub from those below. The drive section arms extend variably and independently to span hole diameters up to 15 in [38 cm] and are

UltraTRAC Tractor Configurations

2 drive

4 drive

3 drive

4-drive tandem

6-drive tandem

fitted with wheels from a wide range of diameters and proprietary designs optimized for the well geometry and borehole conditions. Engineered to withstand the impact of perforating gun detonation as well as the vibration generated in rugose boreholes, the UltraTRAC tractor has low sensitivity to well conditions. The UltraTRAC tractor is a CE certified tool that meets the Low Voltage, Machinery, and Pressure Equipment Directives of the European Union. The Tractor Planner app for  iPad devices can be used to identify UltraTRAC tractor candidates for specific conveyance situations.

Applications High-force extended-reach tractor conveyance: ■ Openhole formation evaluation ■ Openhole formation testing ■ Borehole imaging services ■ Perforating ■ Cement and corrosion evaluation ■ ReSOLVE* instrumented wireline intervention service – Nonexplosive plug setting – High-force axial shifting – Selective shifting with a universal shifting tool (UST) – Milling ■ ABC* analysis behind casing services ■ Production logging

8-drive tandem

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Mechanical Specifications Output Maximum speed† Temperature rating Pressure rating Hole size—min. Hole size—max. Outside diameter† Length‡ Max. pull per drive section† Max. force Power, cable requirements

UltraTRAC Tractor

UltraTRAC Mono Tractor

Openhole logging Cased hole perforating, logging, intervention 3,200 ft/h [975 m/h] 350 degF [177 degC] 20,000 psi [138 MPa] 3.6 in [9.1 cm] 15 in [38.1 cm] 3.375 in [8.57 cm] Drive sections: 2 to 8 Min. (2 drives): 15.35 ft [4.68 m] 8 drives: 39.19 ft [11.94 m] 400 lbf [1,780 N] 3,200 lbf [14,230 N] AC, heptacable

Openhole logging while tractoring Cased hole perforating, logging while tractoring, intervention 2,400 ft/h [730 m/h] 302 degF [150 degC] 20,000 psi [138 MPa] 3.6 in [9.1 cm] 15 in [38.1 cm] 3.375 in [8.57 cm] Drive sections: 2 to 6 Min. (2 drives): 23.45 ft [7.15 m] 6 drives: 46.32 ft [14.12 m] 400 lbf [1,780 N] 2,400 lbf [10,675 N] DC, multiconductor cable (mono and hepta)

† Depending on wheel size ‡ Depending on the configuration and excluding the 2.8-ft [0.85-m] logging head. The incorporated casing collar locator (CCL), head tension cell, addressable cable-release device, and shock absorber are standard features that do not add extra length.

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TuffTRAC and TuffTRAC Mono Cased Hole Services Tractors TuffTRAC Mono Tractor Configurations

Two drive sections

Three drive sections

The modular TuffTRAC* and TuffTRAC Mono* cased hole services tractors employ reverse tractoring and traction control capability through full control of the radial force applied by the tractor arms to operate with improved maneuverability and reduced slippage. Because this force applied by the tractor arms is independent of borehole size, the tractor drives can achieve the same tractoring force in borehole IDs from 3.4 to 10.6 in [8.6 to 26.9 cm]. The tractor’s low sensitivity to borehole conditions allows it to deploy any Schlumberger cased hole service, including perforating and plug setting. The TuffTRAC Mono tractor adds logging-while-tractoring functionality. The two-drive configuration of the TuffTRAC tractor is the shortest tractor available—only 14.2 ft [4.3 m] in length. The Tractor Planner app for iPad devices can be used to identify candidate TuffTRAC tractors. Up to six modular drive sections can be run as needed to push heavy loads. The tractor’s low power requirements reduce stress on auxiliary systems, eliminating the necessity for stops to cool down, and its wheels optimize surface electrical power to achieve

more than 45% conversion efficiency. The tractor achieves a maximum speed of 3,200 ft/h [975 m/h] at relatively low power usage. To increase safety and reliability, the TuffTRAC tractor incorporates a head tension cell, electrical cable release, casing collar log (CCL), and addressable perforating safety switch. Other standard safety components include a multiple-use shock absorber and fail-safe opening system. The TuffTRAC tractor is CE certified for Low Voltage, Machinery, and Pressure Equipment Directives. The Tractor Planner app for  iPad devices can be used to identify UltraTRAC tractor candidates for specific conveyance situations.

Applications ■ ■ ■ ■ ■ ■

Perforating operations Plug setting Production logging ABC analysis behind casing services Cement and corrosion evaluation Mechanical intervention operations

Mechanical Specifications

Four drive sections

Output

Four-drive tandem

Six-drive tandem

Maximum speed Temperature rating Pressure rating Hole size—min. Hole size—max. Outside diameter Length†

Max. pull per drive section Max. force Power, cable requirements

TuffTRAC Tractor

TuffTRAC Mono Tractor

Cased hole perforating, logging, and intervention 3,200 ft/h [975 m/h] 350 degF [177 degC] 20,000 psi [138 MPa] 3.4 in [8.6 cm] 10.6 in [26.9 cm] 3.125 in [7.94 cm] Drive sections: 2 to 8 Min. (2 drives): 11.4 ft [3.5 m] 3 drives: 14.2 ft [4.3 m] 300 lbf [1,330 N] 2,400 lbf [10,680 N] AC, heptacable

Cased hole perforating, logging, logging while tractoring, and intervention 2,400 ft/h [730 m/h] 302 degF [150 degC] 20,000 psi [138 MPa] 3.4 in [8.6 cm] 10.6 in [26.9 cm] 3.125 in [7.94 cm] Drive sections: 2 to 6 Min. (2 drives): 18.2 ft [5.5 m] 3 drives: 21.1 ft [6.4 m] 300 lbf [1,330 N] 1,800 lbf [8,010 N] DC, multiconductor cable (mono and hepta)

† Depending on the configuration and excluding the 2.8-ft [0.85-m] logging head. The incorporated CCL, head tension cell, addressable cable-release device, and shock absorber are standard features that do not add extra length

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MaxTRAC Downhole Wireline Tractor The MaxTRAC* downhole wireline tractor employs an “inchworm” mechanism to extend the reach of wireline logging services in highly deviated and horizontal wells. Its grip design, high expansion ratio, and compatibility with the telemetry system of the logging tools enables it to traverse a wide range of completions in both cased and open holes while logging is conducted to acquire production logging data. The integral three-arm grip of the tractor runs it centralized. A minimum of two tractor sondes are run for standard operations. Up to four sondes can be combined for additional flexibility in difficult well conditions. The tractor sonde uses a spring-loaded cam to grip the casing in one direction. The sonde then pulls the grip section backward against the locking direction

of the cam, which causes the toolstring to move forward. This action is synchronized with the other sondes in the toolstring. The reciprocating action of the sondes produces continuous motion of the conveyed tools. The Tractor Planner app for  iPad devices can be used to identify MaxTRAC tractor candidates for specific conveyance situations.

Applications Conveyance in highly deviated and horizontal wells ■ Logging operations in perforated casing, slotted liners, gravel-pack screens, and in-gauge barefoot completions ■ Perforating ■ Production logging ■

Specifications MaxTRAC Tractor Output

Downward motion of logging tools

Tractoring speed

Standard with 500-lbm [227-kg] load: 1,800 ft/h [549 m/h] Max. with 300-lbm [136-kg] load: 2,500 ft/h [762 m/h]

Mud type or weight limitations

None

Combinability Logging while tractoring

Tools using PS Platform* production services platform telemetry such as the RSTPro* and SCMT* tools

No logging while tractoring

Combinable with most other tools Combinable with perforating services

Special applications

Maximum dogleg severity: 45° per 100 ft [30 m] in 7-in [17.78-cm] casing 30° per 100 ft in 4½-in [11.43-cm] casing

Surface Systems

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Drillpipe-Assisted Wireline Deployment LWF logging-while-fishing service LWF* logging-while-fishing service saves time and reduces cost by enabling the resumption of logging operations during fishing. In most cases, employing LWF service eliminates the conditioning trip required before relogging because the fishing job is converted to a drillpipe-assisted log that completes the original descent in the wellbore. LWF service can be used with most stuck wireline tools. Operations begin by preparing the wireline for cut-andthread fishing. The connected rope sockets on the cable ends are housed in a load-bearing protective torpedo to reestablish both the mechanical connection and electrical communication with the stuck toolstring. The tool overshot and drillpipe are threaded over the cable until the placement depth is reached for the Cable Side Entry Sub (CSES). The CSES is placed to provide an overlapping, continuous log, with the maximum continuous log interval equal to the distance between the casing shoe and rig floor. The wireline passes through the CSES to the outside of the drillpipe to prevent wireline damage during logging. A downhole cable-severing device is also installed to allow retrieval of the wireline if the drillpipe becomes stuck while logging.

The fishing tools on the rig floor are then removed from the wireline, and the tool is repowered to prepare for engagement of the overshot and tool. The speed of the operation now increases because tripping drillpipe is quicker than threading cable through drillpipe. When the stuck tool is reached, engagement is less likely to damage the tool because the reestablished electrical communication allows monitoring tension at the tool in addition to the usual driller’s method. Once the tool is freed, logging is conducted on the TLC tough logging conditions system to continue the recording of continuous or stationary logs.

TLC tough logging conditions system The TLC tough logging conditions system makes it possible to deploy tools for wireline logging in highly deviated or horizontal wells and also in hostile environments and deep wells. Wireline tools are mechanically connected beneath the drillpipe using the Downhole Wet Connector Head (DWCH) and run in to a predetermined latch point. The Pump-Down Wet Connector Head (PWCH) is then threaded through the CSES and pumped down to latch in the DWCH to provide an electrical connection.

The  CSES provides a complete cable seal up to 5,000-psi [34‑MPa] differential pressure. All standard tools are rated to 20,000 psi [138 MPa]. The TLC system enables conducting operations in otherwise impossible conditions. A key component of TLC system operations is thorough prejob planning that accounts for tool compressional and tensile strengths (especially for induction and sonic tools), hole and casing sizes, drillpipe internal diameter and conditions, and well conditions. Because of the longer operational time related to deployment on the TLC system, special considerations apply when well temperatures exceed 350 degF [174 degC]. The logging program must be planned to reduce logging time at high temperatures. Wireline tools are typically rated to 350 degF, and all higher temperature tools use a Dewar flask to delay the well-generated heat from reaching the electronic components. Temperature limits are specified for a holding time beyond which damage occurs to tool electronics.

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Depth Measurement Depth measurement is critical for wireline operations. An integrated depth dual-wheel spooler (IDW) provides calibrated absolute depth measurement recorded on two independent wheels kept constantly in contact with cable. A  fastest wheel logic combined with wheel slippage automatic detection ensures depth accuracy at all times. Other downhole measurements are valuable, but they must be “secured” at the most precise point possible below the Earth’s surface. Decision makers rely on precise depths for mapping geologic intervals, designing completion procedures, and conducting other related operational and financial procedures. If the depth measurement is incorrect, incorrect geologic and economic decisions could result.

Cable and tool friction, especially when calipers are open, cause elastic downhole cable stretch not detected by the IDW at surface. Friction always opposes the movement of tool and cable, so stretch is highest when the tool is moving up and negligible when the tool is moving down. Because log data is recorded while moving up, the tool is physically deeper than what the IDW records on the way up but correctly positioned on the way down. The difference between the log-up and logdown tensions is used to compute the elastic stretch, and a positive correction is applied to the depth before logging up begins. As the friction progressively decreases while logging up, the tool returns to the same zero point when back at surface.

The depth and tension subsystems of the IDW feature alarms and winch shutdown for specified safe operating zones of depth and tension, respectively. The upper and lower limits of the safety zones are called setpoints and are provided for four conditions: ■ low tension ■ high tension ■ top of well ■ bottom of well. Winch operation is shut down automatically when any of the limits established by these setpoints are exceeded.

Surface Systems

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Logging Platforms and Suites

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Scanner Family Rock and Fluid Characterization Services Scanner Family* rock and fluid characterization services scan both radially and orthogonally at multiple depths of investigation to provide a true 3D image of the reservoir. Because the Scanner* services overcome conventional measurement limitations, the tools scan formation volumes to provide new insight into the challenges of formation heterogeneity, anisotropy, and asymmetry. With the ability to measure both in open and cased holes comes the ability to better understand the reservoir.

Openhole Scanner services Litho Scanner* high-definition spectroscopy service measures both inelastic and capture gamma ray spectra to deliver an expanded set of key elemental weight fractions with higher precision and accuracy than previously possible. Determining total organic carbon (TOC) solely from these direct measurements avoids the biases introduced by conventional models and the wait for laboratory analysis. ■ Dielectric Scanner* multifrequency dielectric dispersion service measures permittivity and conductivity for the determination of water-filled porosity (hence water saturation within the total porosity), water salinity, and textural effects. In carbonates, Dielectric Scanner analysis of rock texture delivers a continuous in situ measurement of the Archie mn exponents instead of relying on estimates or waiting for laboratory core analysis; in shaly sands, processing provides a continuous log of the cation exchange capacity (CEC). ■

Wireline Services Catalog

■

Dielectric Scanner

Sonic Scanner

EM Pipe Scanner

Litho Scanner Rt Scanner

Isolation Scanner

Flow Scanner

MR Scanner

Logging Platforms and Suites

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Sonic Scanner* acoustic scanning platform measures compressional and shear slownesses with multiple borehole-compensated monopole and crossed-dipole transducers. The radial and axial measurements of the stress-dependent properties of the rocks are the basis of a comprehensive geomechanical characterization, including classifying formations as isotropic or anisotropic, along with determination of the type and cause of the anisotropy—intrinsic or stress induced from the drilling process. Logging with Sonic Scanner platform can be conducted in both open and cased holes. ■ MR Scanner* expert magnetic resonance service profiles fluid volumes and saturations to provide direct hydrocarbon characterization in any environment, including rugose boreholes, varied formation resistivities and water salinities, heavy- and oilbase muds, low-contrast pay, and thin formations. ■ Rt Scanner* triaxial induction service calculates vertical and horizontal resistivity (Rv and Rh, respectively) from direct measurements while simultaneously solving for formation dip at any well deviation. The result is enhanced estimates of hydrocarbon and water saturations, especially for laminated, anisotropic, or faulted formations. In addition, formation dip and azimuth are calculated for structural interpretation. ■

Cased hole Scanner services Isolation Scanner* cement evaluation service combines classic pulse-echo technology with a new ultrasonic technique—flexural wave imaging— to accurately evaluate any type of cement, from traditional slurries and heavy cements to the latest lightweight cements. Cement channels are pinpointed, and the tool’s azimuthal and radial coverage readily differentiates low-density solids from liquids to distinguish lightweight cements from contaminated cement and liquids. Casing centralization is imaged in high resolution, and corrosion and drilling-induced wear are mapped and quantified. ■ Flow Scanner* horizontal and deviated well production logging system deploys multiple minispinners and arrays of electrical and optical probes to produce real-time multiphase velocity and holdup profiles. The result is an unambiguous realtime production log in nonvertical wells, regardless of phase mixing or recirculation. ■ EM Pipe Scanner* electromagnetic casing inspection tool uses noninvasive electromagnetic measurements to evaluate the integrity of well casings by locating, identifying, and quantifying damage and corrosion. Because the slim-diameter tool easily passes through the tubing shoe, corrosion is measured in production casing without having to pull the completion tubing. ■

Applications Elemental measurements and quantitative mineralogy including TOC log for lithology and salinity-independent hydrocarbon saturation ■ Hydrocarbon volume in carbonates, shaly or low-resistivity sands, and heavy oil reservoirs ■ Location and identification of trapped fluids ■ Quantification of drilling process impact ■ Characterization of rock stresses and long-term formation integrity ■ Resistivity and resonance measurements in thin and low-resistivity beds, regardless of formation dip ■ Confirmation of zonal isolation, channel identification, and information on casing-within-casing centralization in a wide range of cement weights ■ Three-phase production logging in vertical and deviated wells ■ Corrosion damage evaluation in single and multiple casing strings ■

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Openhole Scanner Services Measurement Specifications Litho Scanner Service Elemental yields, elemental weight fractions, TOC, dry-weight mineral concentrations, matrix properties

Dielectric Scanner Service

Sonic Scanner Platform

MR Scanner Service

Rt Scanner Service

Relative dielectric permittivity and conductivity at four frequencies

Compressional and shear Δt, full waveforms, cement bond quality waveforms, anisotropy characterization

T1, T₂, and diffusion distributions; lithology-independent total porosity; bound- and free-fluid volumes; hydrocarbon-corrected permeability; pore-size distribution

Rv , Rh , AIT* tool resistivity logs, spontaneous potential, dip, azimuth

Logging speed

Max.: 3,600 ft/h [1,097 m/h]†

3,600 ft/h [1,097 m/h]

Max.: 3,600 ft/h [1,097 m/h]

Bound-fluid logging: 3,600 ft/h [1,097 m/h] Basic NMR profiling: 1,800 ft/h [549 m/h] T₂ radial profiling: 900 ft/h [274 m/h] High-resolution logging: 400 ft/h [122 m/h] T1 radial profiling: 300 ft/h [91 m/h] Saturation profiling: 250 ft/h [76 m/h]

Max.: 3,600 ft/h [1,097 m/h]

Range of measurement

1 to 10 MeV

(At highest frequency) Permittivity: 1 to 100 Conductivity: 0.1 to 3,000 mS

Standard shear slowness: 2.313 in)

Borehole size—max.

Casing: 13⅜ in

9 in [22.86 cm]

Electromagnetic thickness: 13⅜ in

Outside diameter

1.6875 in [4.29 cm] High-temperature (>302 degF [>150 degC]) operation: 2.25 in [5.72 cm] Flow Scanner system tool: 11.6 ft [3.54 m] With basic measurement sonde, swivel, and head: 26.2 ft [7.99 m] 108 lbm [49 kg]

2.125 in [5.4 cm]

Tension

IBCS-A: 3.375 in [8.57 cm] IBCS-B: 4.472 in [11.36 cm] IBCS-C: 6.657 in [16.91 cm] IBCS-D: 8.736 in [22.19 cm] Without sub: 19.73 ft [6.01 m] IBCS-A sub: 2.01 ft [0.61 m] IBCS-B sub: 1.98 ft [0.60 m] IBCS-C sub: 1.98 ft [0.60 m] IBCS-D sub: 1.98 ft [0.60 cm] Without sub: 333 lbm [151 kg] IBCS-A sub: 16.75 lbm [7.59 kg] IBCS-B sub: 20.64 lbm [9.36 kg] IBCS-C sub: 23.66 lbm [10.73 kg] IBCS-D sub: 24.55 lbm [11.13 kg] Sub max.: 2,250 lbf [10,000 N]

10,000 lbf [44,480 N]

Fishing: 10,000 lbf [44,480 N]

Compression

Sub max.: 12,250 lbf [50,000 N]

1,000 lbf [4,450 N]

3,000 lbf [13,340 N]

Length

Weight

19.7 ft [6.0 m]

110 lbm [50 kg]

† Min. pass-through restriction: 4 in [10.16 cm] ‡ Min. pass-through restriction: 1.813 in [4.61 cm]

Logging Platforms and Suites

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Platform Express Integrated Wireline Logging Tool HGNS

HRMS

HALS

AIT

The Platform Express* integrated wireline logging tool is a revolutionary milestone in wireline logging. Com­ pared with the traditional triplecombo, the Platform Express tool logs faster and more cost effectively because it requires significantly less time from rig-up to delivery of the final answer. The Platform Express tool is less than half the length of the triple-combo—requiring less rathole—and it weighs about half as much. By using integrated sensors and innovative technology to improve pad contact, the Platform Express tool delivers high-resolution imaging measurements that are depth matched and speed corrected in real time. The Platform Express toolstring includes either the AIT* array induction imager tool or High-Resolution Azimuthal Laterolog Sonde (HALS) as the resistivity tool. The Three-Detector Lithology Density (TLD) tool and MicroCylindrically Focused Log (MCFL) are housed in the High-Resolution Mechanical Sonde (HRMS) powered caliper. Above the HRMS are a compensated thermal neutron and gamma ray in the Highly Integrated Gamma Ray Neutron Sonde (HGNS) and a singleaxis acceler­ometer. Numerous innovative features are integrated in the Platform Express toolstring. The specially designed TLD skid reduces hole rugosity effects through improved pad application. The integrated hardware and software of the sensors improves system reliability. The real-time speed correction

provided by the single-axis accelerometer for sensor measurements enables accurate depth matching of all sensors even if the tool cannot move smoothly while recording data. The resistivity, density, and microresis­tivity measurements are high reso­ lution. Logging speed is 3,600 ft/h [1,097 m/h], which is twice the speed at which a standard triple-combo is run. PressureXpress* reservoir pressurewhile-logging service can be combined with the Platform Express tool to efficiently obtain accurate pressure profiles and mobility measurements on the first logging run. The two tools’ data are integrated in real time by the PressureXpress Advisor* pretest quality indicator to produce a more complete interpretation of the reservoir.

Applications DecisionXpress* petrophysical evaluation system ■ Reservoir delineation ■ Hydrocarbon saturation determination and imaging ■ Movable-hydrocarbon  determination  ■ Location of porous and permeable zones ■ Gas detection ■ Porosity analysis ■ Lithology determination ■ Well-to-well correlation ■ Thin-bed analysis ■

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Measurement Specifications Platform Express Tool Output

HGNS: Gamma ray, neutron porosity, tool acceleration HRMS: Bulk density, photoelectric factor (PEF), borehole caliper, microresistivity HALS: Laterolog resistivity, spontaneous potential (SP), mud resistivity (Rm) AIT tool: Induction resistivity, SP, Rm

Logging speed

3,600 ft/h [1,097 m/h]

Mud weight or type limitations

None

Combinability

Bottom-only toolstring, combinable with most tools above

Special applications

Good-quality data in sticky or rugose holes Measurements close to the bottom of the well

Platform Express Tool Component Specifications HGNS

HRMS

HALS

AIT-H and AIT-M Tools

Output

Gamma ray, neutron porosity, tool acceleration

Bulk density, PEF, borehole caliper, microresistivity

Laterolog, resistivity, Rm

Induction resistivity, SP, Rm

Range of measurement

Gamma ray: 0 to 1,000 gAPI Neutron porosity: 0 to 60 pu

Bulk density: 1.04 to 3.3 g/cm3 PEF: 0.9 to 10 Caliper: 22 in [55.88 cm]

0.2 to 40,000 ohm.m

0.1 to 2,000 ohm.m

Vertical resolution

Gamma ray: 12 in [30.48 cm] Porosity: 12 in [30.48 cm]

Bulk density: 18 in [45.72 cm] in 6-in [15.24-cm] borehole

Standard resolution: 18 in [45.72 cm] High resolution: 8 in [20.32 cm] in 6-in [15.24-cm] borehole

1, 2, and 4 ft [0.30, 0.61, and 1.22 m]

Accuracy

Gamma ray: ±5% Porosity: 0 to 20 pu = ±1 pu 30 pu = ±2 pu 45 pu = ±6 pu

Bulk density: ±0.01 g/cm3 (accuracy), 0.025 g/cm3 (repeatability) Caliper: ±0.1 in [±0.25 cm] (accuracy), 0.05 in [0.127 cm] (repeatability)

1 to 2,000 ohm.m: ±5%

Resistivities: ±0.75 ms/m (conductivity) or ±2% (whichever is greater)

Depth of investigation

Gamma ray: 24 in [61.0 cm] Porosity: ˜ 9 in [˜ 23 cm] (varies with hydrogen index of formation)

Density: 5 in [12.70 cm]

32 in [81 cm] (varies with formation and mud resistivities)

AO/AT/AF10†: 10 in [25.40 cm] AO/AT/AF20: 20 in [50.80 cm] AO/AT/AF30: 30 in [76.20 cm] AO/AT/AF60: 60 in [152.40 cm] AO/AT/AF90: 90 in [228.60 cm]

Outside diameter

3.375 in [8.57 cm]

4.77 in [12.11 cm]

3.625 in [9.21 cm]

3.875 in [9.84 cm]

Length

10.85 ft [3.31 m]

12.3 ft [3.75 m]

16 ft [4.88 m]

16 ft [4.88 m]

Weight

171.7 lbm [78 kg]

313 lbm [142 kg]

221 lbm [100 kg]

AIT-H: 255 lbm [116 kg] AIT-M: 282 lbm [128 kg]

† AO = 1-ft [0.30-m] vertical resolution, AT = 2-ft [0.61-m] vertical resolution, AF = 4-ft [1.22-m] vertical resolution

Logging Platforms and Suites

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ThruBit Through-the-Bit Logging Services Drillpipe Wireline dropoff and retrieval tool

No-go collar Hangoff sub

Portal bit

Batteries

Telemetry, memory, gamma ray tool

Neutron tool Density tool Caliper

Induction array tool

ThruBit* through-the-bit logging services provide a full wireline measurement suite from a small-diameter quad- or triple-combo toolstring. This unique conveyance platform enables acquiring logs in wells that are difficult to access, including extended-reach wells where the tools can be pumped down. With a diameter of only 21⁄8  in, the entire logging suite is sufficiently slim to pass through the center of most drillpipe, jars, collars, and out the opening of the Portal* bit. The open borehole is then logged on wireline or as the drillpipe is tripped out of the hole, making it possible to log geometrically complicated wells with greater reliability, at reduced risk, and in less time than alternative conveyance techniques. The logging tools of the ThruBit services suite can also be run as individual components: ■ Telemetry, memory, and gamma ray device provides communications and memory functions for the entire logging string. The gamma ray detector measures naturally occurring gamma rays in the formation as a correlation basis and qualitative evaluation of clay content. The multi­axis accelerometer monitors tool orientation, motion, and vibration. Borehole inclination and temperature are also measured. ■ Array induction tool has five median depths of investigation and three vertical resolutions. The induction tool also incorporates a mud resistivity sensor for making corrections and analyzing borehole fluids. ■ Neutron tool operates in both openhole and cased hole environments to obtain thermal neutron porosity measurements. Corrections can be made for borehole temperature and pressure and environmental factors such as hole size, mud type, mud weight, salinity, and tool standoff.

Density tool measures formation bulk density, photoelectric factor (PEF), and borehole size. Raw measurement processing includes a correction algorithm that preserves overall density accuracy across a wide range of borehole sizes, mud types, and mud weights. The tool’s scintillation detectors are housed in an articulated pad for better contact with the formation, which maintains measurement quality in deviated and rugose holes. A single-arm caliper also helps press the tool against the formation while it measures hole size. ■ ThruBit Dipole* through-the-bit acoustic service obtains both monopole and dipole waveforms along with Stoneley wave acquisition. A 3D anisotropy algorithm transforms the compressional, fast- and slow-shear, and Stoneley slowness measurements with respect to the borehole axes. The resulting referenced anisotropic moduli are used to classify the formation as isotropic or anisotropic and determine whether anisotropy is intrinsic or caused by drillinginduced stress. ■ Spectral gamma ray tool measures the total gamma ray spectra for resolution into potassium, thorium, and uranium. These three most common components of naturally occurring radiation in sands and shales are used to distinguish features, determine clay type, identify radioactivity in sands, and help in determining total organic carbon (TOC) content. ■

ThruBit services provide unparalleled operational flexibility for either conventional wireline logging or through-the-bit conveyance in memory mode. Where conventional wireline logging is not advisable or not possible in vertical or horizontal

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wells, ThruBit services both reduce risk and deliver high-quality data. The hole can be reamed and conditioned using the Portal bit. The logging suite is then run through the drillstring on wireline, and when it reaches the end of the drillstring it is positioned on a hangoff sub so that the logging sensors are passed through the Portal bit and extend into the open hole. The wireline is disconnected and retrieved, and the logging string is used to log in memory mode as the pipe is tripped out.

In wells where a gravity descent is not possible, the logging toolstring is pumped down to the end of the drillstring and positioned for conducting memory mode logging while tripping out. In either horizontal or vertical wells, the logging toolstring can be retrieved before the drillpipe is completely returned to surface to facilitate implementation of completion operations. At all times during deployment and logging, the driller maintains complete control of the drillstring. Circulation and rotation are conducted as needed, and full pressure control is maintained at surface.

Applications Openhole logging in – Horizontal and high-angle wells – Unconventional plays – Unstable boreholes – Poor-quality boreholes (washed out, rugose, or tortuous) ■ Reservoir quality and completion quality data for completion optimization in unconventional plays ■

Measurement Specifications Output

Logging speed Range of measurement

Vertical resolution

Accuracy

Depth of investigation

Mud type or weight limitations Combinability Special applications

ThruBit Logging Services Telemetry, memory, and gamma ray tool: gamma ray, three-axis acceleration, borehole temperature Array induction tool: induction resistivity, mud resistivity, optional SP Neutron tool: thermal neutron porosity Density tool: bulk density, PEF, borehole caliper ThruBit Dipole service:† Compressional and shear Δt, full waveforms, anisotropy characterization Spectral gamma ray tool: gamma ray; corrected gamma ray for uranium; potassium, thorium, and uranium curves Telemetry, memory, and gamma ray; neutron, density, induction, and ThruBit Dipole service: 1,800 ft/h [549 m/h] Gamma ray: 0 to 1,000 gAPI Resistivity: 0.1 to 2,000 ohm.m Neutron: 0 to 60 pu Bulk density: 1.04 to 3.3 g/cm³ PEF: 0.9 to 10 Caliper: 18 in [45.72 cm] ThruBit Dipole service: Δts < 200 us/ft [656 us/m] Monopole: Δtc and Δts < 170 us/ft [558 us/m] Gamma ray: 12 to 24 in [30.48 to 60.96 cm] Resistivity: 1, 2, and 4 ft [0.3, 0.6, and 1.2 m] Neutron: 12 to 15 in [30.48 to 38.10 cm] Bulk density: 9 to 12 in [22.86 to 30.48 cm] ThruBit Dipole service: