baker atlas services catalog 2008_full_v2_1.pdf

IntroductionTable of Contents

Services Catalog

Version Date Revision History2.0 May 2008 Comprehensive text and image editing; added new section, “Deployment Risk

Management”; deleted obsolete services and added new services; incorporatednew “Atlas Orange” color scheme

2.1 August Minor corrections made throughout document.2008

Baker Atlasii Introduction Services Catalog Version 2.1; August 2008

Baker Atlas offers advanced well logging,completion and geoscience services.

Baker Atlas offers a complete range of downhole welllogging services for every environment includingadvanced formation evaluation, production and reservoir engineering, petrophysical and geophysicaldata acquisition services. In addition, perforating andcompletion technologies, pipe recovery, data manage-ment, processing and analysis of open and cased holedata complete the service range.

Offering a proven track record of efficient and professional service execution at the wellsite, BakerAtlas is committed to doing the job right the first time.Baker Atlas believes being number one in the wirelineindustry doesn't mean being the largest company.Instead Baker Atlas prefers to lead the industry inbeing “The Best Choice” for customers by focusingon three key areas and delivering them every day.Baker Atlas stands for Efficiency, Data Accuracy andPeople-oriented Service.

Efficiency

Baker Atlas’ people are committed to providing superior and efficient service through the completejob cycle. Our goal is to offer flawless wellsite execution driven by personnel, enhanced by reliableinstrumentation, efficient conveyance methods andflexible instrument combinations.

Data Accuracy

Baker Atlas recognizes that data accuracy is fundamentaland achieves this through aggressive technologydevelopment. Proactive research and developmentprograms develop new logging instrumentation andadvance the logging interpretation sciences.

People-oriented Service

We believe in maintaining a close working relationshipwith our clients to understand reservoir developmentneeds. When the data acquisition is complete, ourfocus is on delivering maximum value from that data.

In a continuous effort to assist oil and gas companiesin cost-effective exploration and production, BakerAtlas operates a state-of-the-art research and manu-facturing facility. The Houston Technology Center isco-located with Baker Atlas’ global headquarters inHouston, Texas.

Our business centers on assisting our customers to besuccessful in discovering, quantifying and producinghydrocarbon reserves that represent the companies’present and future. Technology is designed to createclient value through improved reservoir description,efficient reservoir development and the reduction ofrisk through timely and accurate data quality.

Health, safety and environmental issues are given the highest priority in Baker Atlas’ logging operations.Comprehensive training programs educate field crewsin safety procedures and the safe handling of hazardous materials.

Every day in oil fields around the world, Baker Atlasfield service personnel, engineers and geoscientists areapplying leading technology to help find, develop andproduce oil and gas. Baker Atlas shares our customers’goal: to understand the reservoir and achieve ultimaterecovery at the lowest overall cost.

Baker Atlas is a division of Baker HughesIncorporated, a Fortune 500 company recognized worldwide as a leading provider of products, services and solutions for thepetroleum industry. Since entering the oilfield in1932 as the Lane-Wells Company, Baker Atlashas grown through a series of mergers andacquisitions including Wedge DiaLog, Z&SGeoscience, SSI and Accutec. Today, buildingon more than seven decades of technologicalbreakthroughs and service excellence, the company serves its worldwide client base as an integral part of Baker Hughes Incorporatedand through joint ventures with partners including GeoMark Research and CompagnieGénérale de Géophysique (CGG).

Introduction

Baker Atlas

Baker Atlas iiiTable of ContentsServices Catalog Version 2.1; August 2008

1. Formation Evaluation Services

Resistivity Logging . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-2

Deep Formation ResistivityHigh-Definition Induction Log (HDIL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-3Dual Laterolog (DLL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-4

Anisotropic Resistivity 3DEX Elite Induction Logging Service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-5

Shallow Investigation InstrumentsMicro Laterolog (MLL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-6Minilog (ML) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-7

Nuclear Logging . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-8

Compensated Z-Densilog (ZDL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-9

Compensated Neutron (CN) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-10

Gamma Ray Log (GR) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-11

Digital Spectralog (DSL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-12

Acoustic Logging . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-13

Cross-Multipole Array Acoustilog F1 (XMAC F1) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-14

Digital Acoustilog (DAL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-15

Magnetic Resonance Imaging . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-16

MR Explorer (MREX) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-17

High-Efficiency Logging . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-18

FOCUS High-Definition Induction Log (F_HDIL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-19

FOCUS Digital Acoustilog (F_DAL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-20

FOCUS Compensated Z-Densilog (F_ZDL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-21

FOCUS Compensated Neutron (F_CN) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-22

FOCUS Gamma Ray Log (F_GR) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-23

Geological Services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-24

Resistivity and Acoustic ImagingWater-Based Mud Formation Resistivity Imager (STAR Imager) . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-25Oil-Based Mud Formation Resisitivity Imager (EARTH Imager) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-26Circumferential Borehole Imaging Log (CBIL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-27Hexagonal Diplog (HDIP) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-28

Caliper ServicesWell Geometry Instrument (WGI) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-29

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Baker Atlasiv Table of Contents Services Catalog Version 2.1; August 2008

2. Formation Testing and Sampling Services

Pressure Testing/Fluid Characterization and Sampling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-2

Reservoir Characterization Instrument (RCI) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-3

Straddle Packer Module . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-4

SampleView IB Service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-5

SampleView IC Service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-6

RCI Single-phase Tanks . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-7

RCI Multi-tank Carrier . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-8

Coring Services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-9

Sidewall Corgun (SWC) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-10

3. Geophysical Services

Borehole Seismic Applications . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-2

Velocity Survey (Checkshot) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-3

Zero Offset Vertical Seismic Profile (ZVSP) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-4

Surface Seismic AVO Calibration . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-5Walkaway VSP, 3-D VSP

2-D and 3-D Imaging . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-6

Hydraulic-Fracture Monitoring . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-7

Downhole Seismic Services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-8

Downhole InstrumentationDownhole Receiver Array Geochain (GCN) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-8Digital Multi-level Downhole Seismic Array (GWV) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-9Multi-level Slimhole Receiver (MSR) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-10PipeSeis (PSR) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-11Buried Gun Array . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-12

Surface InstrumentationSeismic Logging Systems (SLS) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-13Integrated Borehole Seismic Navigation System (TASMAN) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-14

Energy Sources and Energy Source Controllers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-15

VSFusion Borehole Seismic Processing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-16

2-D Imaging . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-16

3-D Migration; 3-C, 3-D Migration; 4-C Processing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-17

3-D VSP Processing, Interpretation and Integration . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-18

Q-Compensating Surface Seismic Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-19

Rotary Sidewall Coring Tool (RCOR) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-9

Baker Atlas vTable of ContentsServices Catalog Version 2.1; August 2008

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3. Geophysical Services (continued)

Special Processing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-20

Post-Survey Modeling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-21

2-D and 3-D VSP Inversion . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-22

Presurvey Modeling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-23

4. Reservoir and Production Services

Cased Hole Formation Evaluation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-2

Reservoir Performance Monitor (RPM) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-3

PDK-100 (PDK) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-4

Production Logging . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-5

Production Optimization Log and Reservoir Information Solutions (POLARIS) . . . . . . . . . . . . . . . . . . . 4-6

Production Logging Services (PRAL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-7

FlowmetersContinuous Spinner Flowmeter (FMCS) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-8Folding Impeller Flowmeter (FMFI) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-9Basket Flowmeter (FMBK) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-10

Fluid Composition LogsNuclear Fluid Density (FDN) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-11Water Holdup Indicator (WHI) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-12

Flolog/TracersNuclear Flolog (NFL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-13Tracerlog (TRL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-13

Pulsed Neutron Holdup Imager (PNHI) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-14Hydrolog (HYDL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-15

Surface Readout Pressure Gauge (SRPG) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-16

Miscellaneous Cased Hole ServicesNoise (Sonan) Log (SON) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-17Temperature Log (TEMP) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-18

Pipe Evaluation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-19

Vertilog Service (VRT) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-20

Digital Magnelog Service (DMAG) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-21

Imaging Caliper Log (ICL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-22

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5. Completion and Mechanical Services

Cement Evaluation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-2

Segmented Bond Tool (SBT) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-3

Radial Analysis Bond Log (RAL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-4

Acoustic Cement Bond Log (CBL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-5

Pipe Recovery . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-6

Overview of Pipe Recovery Operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-6

Pipe Recovery Log (PRL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-7

Free Point Indicators (FPI) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-8Spring Anchor Free Point Indicator (SAFP) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-9Magna-Tector Free Point Indicator (MAFP) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-10

String Shot Backoff (BO) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-11

Chemical Cutter (CC) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-12

Jet Cutter (JCS) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-13

Noise (Sonan)/Temperature Log (SON/TEMP) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-14

6. Completion and Perforating Services

Perforating . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-2

Perforating Charges Overview . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-3

Dynamic Underbalance Optimization Process (DUO) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-4

StimGun Propellant-Assisted Perforating Products . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-5

XLD (eXtreme Low Debris) Perforating Systems . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-6

PERFFORM Low Debris Perforating Systems . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-7

2” and 2 1⁄2“ Low Swell Guns (XPLS) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-8

Horizontal Oriented Perforating System (HOPS) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-9

Snapshot CT Live Well Deployment System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-10

Stackable Gun System (SGS) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-11

Inter-Gun Automatic Release (IGAR) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-12

Model J-Gun Brake (J-GB) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-13

Electro-Magnetic Orienting Perforating (EMO) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-14

Coiled Tubing Conveyed Perforating (CTCP) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-15

One-Trip Perforate and Completion Systems (NeoTrip) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-16

Perforate and Gravel Pack Completion System (PDP) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-17

TCP Azimuthally Oriented Perforating (TCP-AOP) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-18

Parallel Perforating System (PSI) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-19

Tubing-Conveyed Dual String Perforating System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-20

Guardian II/EBW Perforating Package (GDN) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-21

Baker Atlas viiTable of ContentsServices Catalog Version 2.1; August 2008

7. Deployment Risk Management

Wireline Conveyance Systems . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-2

Pipe Conveyed Logging (PCL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-3

Tractor Conveyed Logging (WTCL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-4

Coiled Tubing Conveyed Logging (CTCW) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-5

Pump Down Conveyance (TDP) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-5

Risk-Reduction Technologies . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-6

Well Intervention Modeling Services (CERB) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-7

High-Tension DevicesHigh-Strength Wirelines (XSMC) (XSSC) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-9Powered Capstan (PSW) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-10Wireline Jars (EEJ) (ISJ) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-11

Advanced Conveyance DevicesFlywheels (RHRA) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-12Positioning Devices (RLSC) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-12Roller Assemblies (ROLI) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-12Swivels (SWVL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-13Knuckle Joints (KNJ) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-13Hole Finders (HFD) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-13

Contingency Services and Devices . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-14Logging While Retrieving (LWR) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-15Multi-Conductor Releasable Cablehead (MRCH) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-16Single-Conductor Releasable Tool (ART) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-17Hydraulic Wireline Severing Tool (HWST) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-18Surface Wireline Cutters (RWCC) (RWC) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-18

8. Hostile Environment Services

Extreme HPHT Logging Instruments (Nautilus) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8-2

9. Data Delivery/Management Services

Data Delivery Service (WellLink) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9-2

10. Geoscience Services

Acoustic Waveform Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-2

Geomechanics Services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-3

Nuclear Magnetic Resonance Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-4

Resistivity Processing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-5

Diplog Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-6

Table of Contents

Table of Contents

Baker Atlasviii Table of Contents Services Catalog Version 2.1; August 2008

10. Geoscience Services (continued)

Borehole Image Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-7

Cased Hole Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-8

Production Log Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-9

Pipe Evaluation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .10-10

11. Service Name and Mnemonic Lists

By Category . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11-2

Alphabetical . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11-6

Index . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11-8

Resistivity LoggingNuclear LoggingAcoustic LoggingMagnetic Resonance ImagingHigh-Efficiency LoggingGeological Services

1. Formation Evaluation Services

I

Baker Atlas1-2 Formation Evaluation: Resistivity Logging Services Catalog Version 2.1; August 2008

Resistivity and depth were the first logging measurements ever recorded, and resistivity or its reciprocal,conductivity, is virtually always recorded as part of openhole logging operations. Present-day technologycombines other measurements such as neutron, density, acoustic, and magnetic resonance imaging to quantifyeffective porosity, saturations and permeability. Hydrocarbon evaluation has evolved to logging in morecomplex environments, and as oil fields age around the world, more sophisticated equipment is required toextract hydrocarbons more efficiently and economically. This new marketplace demands an instrument thatcan look ever deeper into the formation and resolve increasingly thinner structures. Baker Atlas meets thisneed using the High-Definition Induction Log (HDILSM) service along with the powerful computationalcapabilities of the ECLIPSSM surface acquisition system. This flexible induction device is designed toaccommodate a wide range of subsurface combination options with other tools.

In addition to conventional openhole formation evaluation measurements, we now offer state-of-the-artanisotropic evaluation services. The 3D Explorer (3DEX EliteSM) Induction Logging Service is a unique formation evaluation instrument designed to efficiently and economically identify and quantify hydrocarbonsin thinly bedded low-resistivity pay zones. The 3DEX instrument’s unique multi-component resistivitymeasurement determines Rh and Rv to identify and quantify hydrocarbon volume in anisotropic formations.

More in-depth information for each service is available in Baker Atlas brochures.

Please contact your local customer service representative, or log on to www.bakeratlasdirect.com for moreinformation and a complete list of Baker Atlas services.

Section Contents/Solution Highlights Matrix

Technology

High-Definition Induction LogDual Laterolog3DEX Explorer (3DEX Elite)Micro LaterologMinilogFOCUS High-Definition Induction Log** Located in the High-Efficiency Logging Section on page 1-18

D

eep

For

mat

ion

Resi

stiv

ity

Res

isti

vity

Ani

sotr

opy

H

igh-

Reso

luti

on R

esis

tivi

ty/T

hin

Bed

s

Low

Res

isti

vity

Pay

D

rillin

g Fl

uid

Inva

sion

Pro

file

Sal

ine

Dril

ling

Flui

ds

– H

ighl

y Re

sist

ive

Form

atio

ns

F

resh

For

mat

ion

Wat

er –

Unk

now

n R w

Sh

allo

w-In

vest

igat

ion,

Rxo

XXX

X

X

X

XXXX

X

XXX

XX

XXX

X

XXX

Resistivity Logging

Improved Rt Results in Improved Sw and More Accurate Reserve Estimates

Determine Accurate Formation Resistivity

Baker Atlas 1-3Formation Evaluation: Resistivity LoggingServices Catalog Version 2.1; August 2008

OperationThe HDIL subsurface instrument is a multi-receiver, multi-frequency induction device. Multiple receivers provideformation resistivities at six depths of investigation, rangingfrom 10 to 120 inches (0.25 to 3 m). The longer receiver coilspacings enable the estimation of Rt, even in the presence ofdeep invasion; the shorter spacings provide the informationto correct for borehole and near-borehole effects.

Hydrocarbon evaluation in complex environments requirestechnologies that can look deeper into the formation andresolve thinner structures. In thinly bedded hydrocarbon-bearing reservoirs and in the presence of deep drilling fluidinvasion, HDIL measurements provide more accurate formation resistivity data than conventional induction systems.Using the HDIL service in these conditions results in betterreservoir description, more accurate water saturation (Sw)determination and a detailed evaluation of the drilling fluidinvasion profile.

HighlightsSuperior measurements in deeply invaded formations Detailed evaluation of the drilling fluid invasion profileInversion processing provides thorough analysis of allavailable dataFlexible combination options

BenefitsMore accurate formation resistivity, water saturation andreserves estimatesImproved evaluation in deeply invaded formations

Specifications – Series 1515

The High-Definition Induction Log (HDILSM) service, a full-spectrum array-type induction logging service, provides formation resistivities at multiple depths ofinvestigation in freshwater and oil-based drilling mudsystems. The combination of the HDIL high-vertical resolution and deep-investigating measurements withinversion processing provides a detailed analysis of formation resistivity (Rt), flushed zone resistivity (Rxo)and depth of invasion.

Inversion processing of HDIL data provides improvedtrue formation resistivity (Rt) and flushed zone resistivity (Rxo) values, as well as drilling fluid invasion profile information. The invasion profile intrack 1 distinguishes the fully flushed, transition andundisturbed regions. Track 2 shows Rt, Rxo and theresolution-matched measurements, while track 3shows a radial resistivity image.

HDIL – High-Definition Induction Log

Description Specification

Length 27.1 ft 8.27 m

Diameter 3.63 in. 92.1 mm

Pressure Rating 20,000 psi 137.9 MPa

Temperature rating 350º F 177º C

Weight 433 lb 196 kg

Reliable Formation Resistivity in Saline Drilling Fluids or High-Res Formations

DLL – Dual Laterolog

Log in High-Resistivity Environments

Baker Atlas1-4 Formation Evaluation: Deep Formation Resistivity Services Catalog Version 2.1; August 2008

OperationThe Dual Laterolog instrument simultaneously produces a deep investigation resistivity and a shallow investigation resistivity measurement.

HighlightsDetermine formation resistivity in saline mud systems and high formation resistivities Qualitative permeability indicatorFormation evaluation, including hydrocarbon/water contacts

BenefitsEstimate of hydrocarbon saturation via measure-ment of formation resistivity and invasion profile in the presence of saline drilling fluids Estimate of movable hydrocarbons in the presenceof saline drilling fluids


Dual Laterolog instruments are electrode toolsdesigned to produce reliable formation resistivitymeasurements in boreholes containing salinedrilling fluids. They operate by “focusing” a surveycurrent into the formation. Dual Laterolog instru-ments are superior to induction instruments inhigh-resistivity (>100 ohm-m) formations and/orwellbores with drilling fluids more conductive thanthe in-situ formation waters.





Temperature 350º F 177º C

Weight 278 lb 126.1 kg

XX00XX00

Compute Horizontal and Vertical Resistivity

3DEX Elite – 3D Explorer Induction Logging Service

Determine Resistivity Transverse Anisotropy

Baker Atlas 1-5Formation Evaluation: Deep Formation ResistivityServices Catalog Version 2.1; August 2008

OperationThe 3DEX Elite service employs sets of Z-direction coils coaxialwith the instrument and additional orthogonally mounted “X” and“Y” coil arrays. Inversion processing of 3DEX Elite data allowscomputation of horizontal and vertical resistivity, enabling determi-nation of the resistivity transverse anisotropy. Conventional loggingtools generate currents parallel to the formation bedding layers inboreholes that are drilled perpendicular to the formation. In thissituation, instruments such as the High-Definition Induction Log(HDIL) service measure the horizontal conductivity. In thinly laminated or thinly bedded reservoirs, the horizontal conductivityis governed by the conductive shaly laminae. For example, in ahydrocarbon-bearing sand-shale sequence, the shale resistivitiescould measure 1 ohm-m while hydrocarbon-bearing sand layerscould measure 10 ohm-m, with a net-to-gross of 50 percent. Aresultant horizontal resistivity measurement of 1.8 ohm-m wouldbe observed. The highly conductive shale dominates the measure-ment, obscuring the presence of the hydrocarbons. The verticalconductivity measurement is very sensitive to the presence of thehydrocarbon-filled sand layers and would increase to about 6 ohm-min the example described above. This physical phenomenon isresistivity transverse anisotropy.

HighlightsDetermine accurate Sw in thinly bedded sand shale sequencesDetermine resistivity anisotropy, formation dip and azimuth


The 3D Explorer (3DEX EliteSM) Induction Logging Service is aunique formation evaluation instrument designed to efficientlyand economically identify and quantify hydrocarbons in thinlybedded, low-resistivity pay zones. Improved engineering hasnow enhanced the service, providing more measurements,better accuracy and increased logging speed.

Conventional resistivity tools often miss hydrocarbon pay zonesin thinly bedded sand-shale sequences. They measure hori-zontal (bed-parallel) resistivity, and the measurements aredominated by the low-resistivity shale laminae, not by thehigh-resistivity, hydrocarbon-bearing sand laminae. In manyhorizons, these formations contain significant reserves andproduce commercially. The 3DEX Elite tool enables determi-nation of bed parallel (R HORIZONTAL) and bed-normal (R VERTICAL) resistivities and can be run in combinationwith the High-Definition Induction Log (HDILSM).







New petrophysical models have been developedthat allow for the application of horizontaland vertical resistivity in a true reservoirdescription model that accurately determinesthe hydrocarbon saturation of thin-beddedlaminar sands and better productivity estimates.

In thinly bedded reservoirs, here a sand-shalesequence in which the hydrocarbon-bearingsands measure 10 ohm-m and the conductiveshales 1 ohm-m at 50% net-to-gross, traditionalinduction logging tools measure 1.8 ohm-m in a vertical well. The 3DEX Elite provides an additional measurement, the vertical resistivityat 5.5 ohm-m, which is much more sensitive tothe hydrocarbon-bearing sand layers.

BenefitsMore accurate formation resistivity, water saturation andreserves estimates in thinly laminated reservoirsBetter resistivity estimates inhighly deviated wells

Note:

High-pressure

equipment

available on

request

Micro Laterolog run in combination with Dual Laterolog

OperationThe Micro Laterolog is typically run in situationswhere the drilling fluid is saline and formation resis-tivity is high. A one-arm caliper is an intergal part ofthe tool and provides a continuous caliper curve. TheMicro Laterolog can also be run when fresh drillingmuds are used, but corrections become large whenmudcake thickness exceeds 1/4 inch (6.4 mm).

HighlightsDetermine flushed zone resistivity

BenefitsMovable hydrocarbon indication in salt muds

Specifications – 1233 Series*

The Micro Laterolog is a focused-pad device that measures the resistivity of the invaded zonenear the borehole. It is designed to work bestwhen the resistivity of the flushed zone is muchgreater than that of the mudcake, a situationwhere the Minilog performs poorly. When used inconjunction with deeper-reading resistivity meas-urements, the MLL can provide a good indicationof movable hydrocarbons.

Measurements Adjacent to Wellbore Measure Flushed Zone Resistivities

Indicator of Movable Hydrocarbons in Salt Muds

Baker Atlas1-6 Formation Evaluation: High-Resolution Resistivity Services Catalog Version 2.1; August 2008

MLL – Micro Laterolog







*Contact your Baker Atlas representative for additional series.

Measurements Adjacent to Wellbore Measure Mudcake/Flushed Zone

Qualitative Permeability Indicator in Fresh Mud Systems

Baker Atlas 1-7Formation Evaluation: High-Resolution ResistivityServices Catalog Version 2.1; August 2008

ML – Minilog

OperationThe 2-inch Normal Resistivity measures up to 4 inches(101.6 mm) out from the pad face, whereas the 1-inchLateral Resistivity measurement has a depth of investigationof approximately 1.5 inches (38.1 mm). Thus in usual fresh-mud situations, the RNML curve, reading through the mudcake to the formation with drilling fluid, reads higherthan the mudcake reading RLML curve, indicating mudcakeand permeability. In impermeable formations the curvesshould overlay and can even exhibit a “negative” separation.Under favorable conditions, the Minilog can also measurethe Flushed Zone Resistivity quantitatively. Like the MicroLaterolog, the Minilog includes a one-arm caliper pad device.

HighlightsIdentify zones with developed mudcake Determine flushed zone resistivity

BenefitsPermeability indication in fresh mud systems for completion designsMovable hydrocarbon indication for completion decisions


The Minilog is a pad device that measures resistivity attwo shallow, but different depths of investigation. Thisallows the identification of mudcake, and therefore permeable formations.








Minilog (ML)

Nuclear Logging

Baker Atlas1-8 Formation Evaluation: Nuclear Logging Services Catalog Version 2.1; August 2008

Reliable economic evaluation of a reservoir requires reasonable knowledge of certain fundamental reservoirproperties. Although rock recovered by coring methods is the cornerstone of formation evaluation, wirelinedata are more universally available for determining the fundamental reservoir properties.

Logging devices that measure density characteristics of the rocks traversed with the instrument are veryimportant to openhole log analysis. Baker Atlas’ nuclear tools provide an array of accurate formation porosityand lithology information. Baker Atlas’ nuclear tools acquire neutron porosity, natural gamma ray spectrometry,density porosity and photoelectric effect measurements along with basic gamma ray measurements. Thecombination of these measurements can simplify porosity and lithology evaluation in difficult reservoirs.

Of all the log measurements that are sensitive to porosity in rock, the density measurement is the mostimportant because it provides a bulk density (rhob) value that is most sensitive to effective formation porosity.The photoelectric absorption index (Pe) of the Compensated Z-DensilogSM service is particularly useful indetermining formation lithology. The principal use of neutron logs is to identify porous rock and determinean apparent porosity. If the formation is shale-free, the pores filled with liquid, and the matrix lithologyknown, the neutron log can be used to determine the porosity. Comparing the neutron log data to other logdata often resolves the presence of gas, volume of shale and matrix type.

More in-depth information for each service is available in Baker Atlas brochures. Please contact your local customer service representative, or log on to www.bakeratlasdirect.com for more information and a completelist of Baker Atlas services.


Technology

Compensated Z-DensilogCompensated NeutronGamma Ray LogDigital SpectralogFOCUS Compensated Z-Densilog*FOCUS Compensated Neutron*FOCUS Gamma Ray Log** Located in the High-Efficiency Logging Section on page 1-18**When combined with other porosity devices

Po

rosi

ty

Bulk

Mat

rix

Lit

holo

gy**

Min

eral

ogy

Det

erm

inat

ion*

*

Id

enti

fy G

as**

C

lay

Typ

e

S

and

/Sha

le**

Del

inea

tion

L

itho

logy

Cor

rela

tion

Vol

ume

of S

hale

XX

XX

X

X

XX

XX

XX

XX

XXX

X

XX

X

XXXXXXX

XX

XXX

Evaluate Complex Lithologies

ZDL – Compensated Z-Densilog

Determine Both Formation Porosity and Lithology

Baker Atlas 1-9Formation Evaluation: Nuclear LoggingServices Catalog Version 2.1; August 2008

OperationInstrument features that enhance quality include: scintillationdetectors for increased count rates and improved repeatability,256-channel spectrum recording for advanced signal processing, real-time gain compensation for temperature-related changes in detector response, compensation of bulkdensity for variable mudcake composition and thickness,and Dewar flasks that protect heat-sensitive downhole electronics for use in higher temperature wells. A one-armmotorized caliper is an intergal part of the tool and providesa continuous caliper curve.

HighlightsAccurate determination of formation porosity and lithologyAccurate determination of formation minerals Accurate determination of gas zonesAccurate determination of fluid properties

BenefitsPorosity evaluation even in the presence of complex mineralogyComplex mineralogy evaluationDetermine gas/water contacts for completion designs

Specifications – Series 2234*

The Compensated Z-DensilogSM service provides bothformation bulk density and the photoelectric absorptionindex (Pe) data. These measurements allow evaluationof complex formations determining lithology and porosityin such formations. Because the photoelectric absorptionof gamma rays depends strongly on atomic number, themeasured values of Pe are directly related to the forma-tion’s composition. The Pe measurement is not signifi-cantly dependent on porosity or fluid content, making itparticularly useful in determining formation lithology.








Z-Densilog (ZDL)

X000X000

Baker Atlas1-10 Services Catalog Version 2.1; August 2008

OperationThe Compensated Neutron instrument utilizes a source and two detectors. The surface computer calculates theapparent porosity using the ratio of the count rates from the two detectors.

The Compensated Neutron has fewer borehole effects thanother types of neutron logs. This instrument design is usefulin rough or washed-out boreholes.

Neutron tools respond to the amount of hydrogen per unitvolume of formation or hydrogen index. Gas and some oilshave a much lower hydrogen index than water, and the toolresponds to the reduced hydrogen content by indicating alower apparent porosity. In gas zones, the apparent porositywill read lower than in water zones of the same porosity toproduce a “gas effect” on the logs.

HighlightsPorosity analysisLocate gas (when combined with Compensated Densilogand/or Acoustilog) Identify lithology when used with other porosity devices

BenefitsDetermine gas/water contactsInput as shale indicator provides for accurate computedlog analysis for completion decisions


Neutron logs are primarily used for identification ofporous formations and the estimation of porosity. Often,it is possible to distinguish gas zones from oil or waterzones by the comparison of a neutron log with anotherporosity log or with information from core analysis.Combining the Compensated Neutron with a Z-Density(or Densilog) or an Acoustilog survey provides accurateporosity values, shale content and lithological information.








Formation Evaluation: Nuclear Logging

Locate Gas When Run in Combination with Compensated Density Log

Determine Formation Porosity

CN – Compensated Neutron

Baker Atlas 1-11Services Catalog Version 2.1; August 2008

Estimate Shale Content and Sand Count for Reserve Calculations


Identify Formation Boundaries

GR – Gamma Ray Log

OperationThe instrument has analog and digital varieties providingcombination flexibility with all instruments, includingdownhole seismic applications. The Gamma Ray instrumentcan be run in any liquid or air-filled hole, either cased oruncased. In cased holes, a Casing Collar Log can also berecorded simultaneously.

HighlightsMake depth correlations with other logs Determine formation profilesEstimate shale content in reservoir rocks Delineate stratigraphic boundaries for several production logs

BenefitsLithology correlation between wellsEstimation of shale content for advanced log analysisQualitative permeability indicator for completion decisions


The Gamma Ray instrument measures the naturalradioactivity of the formation being surveyed. The intensity of radiation gives an indication as to the typerock present along the wellbore. The gamma ray curveusually correlates with the SP curve.

Gamma Ray logs are effective in distinguishing permeable zones by virtue of the fact that radioactiveelements tend to be concentrated in the shales, whichare impermeable, and are much less abundant in carbonates and sands, which are generally permeable.








X000X000


OperationDiscriminating the total gamma ray signal into discreteenergy levels or windows infers the individual amounts ofpotassium (K), uranium (U), and thorium (Th). Virtually allof the gamma radiation detected by downhole instrumentscan be classified in one of three categories. As a result, certain lithology ambiguities which often exist when usingonly total gamma ray signal can be resolved.

For example, given a high total gamma ray count over a 40-foot interval, the signal could be indicative of a shalezone. If that signal were composed mostly of uraniumgamma rays, it could be indicative of a fault plane whereuranium-carrying fluid had migrated.

Improved acquisition allows the Digital Spectralog tool tooperate at three times the standard recommended loggingspeed of the standard Spectralog instrument without loss ofstatistical precision. The Digital Spectralog tool can becombined with any other openhole logging instruments.

HighlightsLithology identification and correlation between wellsDetermination of clay type and clay content Locating uranium by-product buildup in a cased wellsIdentify depleted zones and water encroachmentIdentifying potential fracture zones

BenefitsMake completion decisions based on fractures, high per-meability zones; avoid depleted zones or water contactsAccurate shale volume for advanced log analysis input


The Digital Spectralog SM (and combined Digital GammaRay) service differs from a standard gamma ray instru-ment – which records total gamma rays – in that it alsomeasures the discrete energy of each gamma raydetected. By separating the total gamma ray signal intoits components, the Digital Spectralog service can assistcustomers in locating fracture zones, identifying thelithology of subsurface formations, measuring bed thick-ness, correlating zones of interest between wells, andmaking qualitative estimates of formation permeability.








Analyze Depositional Environments and Define Facies

DSL – Digital Spectralog

Define Lithology and Identify Potential Productive Zones


X000X000

X000


Acoustic Logging

Formation Evaluation: Acoustic Logging

Many earth science disciplines benefit from information derived from acoustic logging data. Digital acousticmeasurements provided by Baker Atlas services play an important role in a variety of petroleum exploration andproduction applications. Full-wave, monopole and dipole acoustic data is used in petrophysical, geophysical,geological, drilling, geomechanical, reservoir engineering and production applications.

The industry-leading Baker Atlas digital acoustic logging services provide quality compresssional and shear wavedata including data from unconsolidated, low-velocity formations. A “Best-in-Class” Stoneley wave data is alsoavailable. These systems provide improved reservoir characterization and petrophysical property determinationto maximize well and reservoir productivity.

More in-depth information for each service is available in the Baker Atlas document, Acoustic LoggingApplications supplementary guide. Please contact your local customer service representative, or log on to www.bakeratlasdirect.com for more information and a complete list of Baker Atlas services.

More in-depth information for each application is available in the following Baker Atlas brochures.


Technology

Cross-Multipole Array Acoustilog F1Digital Acoustilog FOCUS Digital Acoustilog** Located in the High-Efficiency Logging Section on page 1-18**When combined with other porosity devices

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X X X XX


Accurate and Reliable Data Even in Ultra-Slow Formations

XMAC F1 – Cross Multipole Array Acoustilog F1

“Best-in-Class” Acoustic Service


OperationThe Baker Atlas XMAC F1 service builds on the previousXMACSM Elite instrument already accepted as the benchmarkfor acquiring quality compressional and shear measurementsover a broad range of borehole environments. The XMAC F1service provides the best quality monopole and dipole meas-urements in unconsolidated formations (Δtc>250 μs/ft, Δts>1200 μs/ft) where competitor tools have had difficulties performing.

A new telemetry scheme allows acquisition of a full data set twice as fast as the XMAC Elite service. Petrophysicistscan now easily get acceptance for acquiring data that otherwisewould have been cost-prohibitive when rig time is high. Itallows Baker Atlas to record a full data set for later retrievaleven if the need for the data is not apparent at the time ofacquisition. Typical logging speed for inline and cross-dipole,full monopole and Stoneley data was 15 ft/min (4.6 m/min),while the XMAC F1 instrument records the same data at 30 ft/min (9.1 m/min).

Highlights“Best-in-Class” full wave monopole and cross-dipole dataeven in unconsolidated, low-velocity formations Same depth co-located and matched dipole transmitters forcross-dipole anisotropy measurements around boreholeMost comprehensive dataset and lowest frequency transmission in industry providing true formation slownessIndustry’s highest dynamic range providing reduced uncertainties


The Cross Multipole Array Acoustilog F1 (XMACSM F1)service is a fullwave monopole, inline dipole and cross-dipole instrument that was developed through technologytransfers and licensing agreements from ExxonMobil(source technology) and Shell (receiver technology).

In this Gulf of Mexico Pleistocene example,ultra-slow formation data acquisition presentsa difficult environment to determine accurateshear slowness. Shear slowness values are inthe 800-900 usec/ft range. A comparison ofthe XMAC F1 demonstrates the superiorcapability of the XMAC Elite.

The Frequency vs. Amplitude graph demonstrates the significantly improved frequency and amplitude response of XMACF1 transmitters.







The orientation of the fracture system indicated on the azimuthal anistropy map is confirmed by the image data.

0 200 400 600 800 1000

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Frequency (Hz)

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XMAC Elite

XMAC

Frequency Spectrum12 22

900 200

0 19500 0 19500

Shear Slowness+800 µsec/ft

Caliper 22"

GRDTS

BenefitsRig time savings through single-passdata acquisition at 30 fpm (9.1 mpm)Superior quality shear and compressional measurements foraccurate seismic tie-in and rockproperty informationPorosity determination, permeabilityindexing, hi-res processingAnisotropy analysis for FRACdesign, geomechanics


Compressional Slowness in All Formations & Shear Slowness in Fast Formations

DAL – Digital Acoustilog

High-Resolution Tool Measures Compressional Monopole Data


OperationThe instrument efficiently and accurately records compressional travel times using an array of fourdownhole receivers and two low-frequency transmitters.The waveform correlation is insensitive to cycle skip-ping, making it particularly effective in gas-saturatedformations, rugose wellbores and borehole washouts.The instrument also provides through-casing loggingand cement bond evaluation.

HighlightsAccurate and efficient wellsite determination of compressional travel time (delta t)Through-casing acoustic logging Qualitative cement bond evaluationIdentify lithology and gas zones

BenefitsProvide acoustic-derived porosity for water saturationsProvide seismic correlation through compressionaland shear synthetic seismograms in fast formations


The Digital AcoustilogSM (DAL) logging systemacquires high-resolution, waveform acoustic datain open and cased holes. The instrument providesacoustic-derived porosity in openholes as well ascement bond evaluations in cased holes. Waveformamplitude, slowness and arrival time (delta t) processing of the raw data can be incorporatedinto advanced log analysis programs to evaluatefractures, sand production and rock properties.

Efficient acquisition of compressional arrival time(delta t) in a wide range of borehole environments.








The DAL can be used for qualitative cement evaluation.

Good Overall

Cement Job

Fast

Formation

Free Pipe

Top of Cement

Partial Bonding

VDL (MICS)

X000

Baker Atlas1-16 Services Catalog Version 2.1; August 2008Formation Evaluation: Magnetic Resonance Imaging

Magnetic Resonance Imaging

The MR ExplorerSM (MREXSM) service, the latest-generation magnetic resonance openhole wireline loggingtool, delivers the benefits of previous nuclear magnetic resonance (NMR) systems while acquiring data morequickly and providing high-quality results in almost any borehole environment. The answers provided by theMREX service reduce uncertainty when evaluating reservoirs and identify hydrocarbon-bearing intervals formaximizing recovery.

A pioneer in NMR logging, Baker Atlas provides more than a decade of data acquisition and interpretationexpertise on every NMR logging job. This experience was leveraged to develop the proprietary technologyknown as the MR Explorer (MREX) to deliver best-in-class NMR answers. The strengths of previous NMRlogging technologies have been combined with new features to improve performance in the downhole environment by increasing acquisition efficiency and enhancing data quality.

More in-depth information for each application is available in the Baker Atlas MREX brochure. Please contactyour local customer service representative, or log on to www.bakeratlasdirect.com for more information and acomplete list of Baker Atlas services.

Solution Highlights Matrix

Objective Oriented Acquisitions (OOA) for the MR Explorer Service

Acquisition Objectives Deliverables*

PoroPerm • Porosity • Φt, Φc, CBW, BVI, BVM, kNMR • Permeability

PoroPerm + Light Oil** • Porosity • Φt, Φc, CBW, BVI, BVM, kNMR • Permeability • Acquisition sequences for oils with • Characterize and quantify oil in pore spaces viscosities from 1 cp to 10 cp.

PoroPerm + Medium Oil** • Porosity • Φt, Φc, CBW, BVI, BVM, kNMR • Permeability • Acquisition sequences for oils with • Characterize and quantify oil in pore spaces viscosities from 10 cp to 25 cp. PoroPerm + Gas** • Porosity • Φt, Φc, CBW, BVI, BVM, kNMR • Permeability • Acquisition sequences for gas and • Characterize and quantify gas and hydrocarbons with viscosities of light hydrocarbons in pore spaces less than 1 cp.

PoroPerm + Heavy Oil • Porosity • Φt, Φc, CBW, BVI, BVM, kNMR • Permeability • Acquisition sequences for oils with • Characterize and quantify heavy viscosities greater than 20 cp. oil in pore spaces

FAST BW • Permeability calculated in combination • CBW, BVI, kBW with conventional porosity measurements • High-speed acquisition consumes no additional rig time when combined with triple combo *Definitions Φt Total NMR porosity Φc Effective NMR porosity CBW Clay bound water BVI Bulk volume irreducible water BVM Bulk volume movable fluid kNMR Permeability calculated from NMR kBW Permeability calculated from NMR bound water data and conventional porosity measurements ** Consult your Baker Atlas representative for the optimal OOA for characterizing both oil and gas within the reservoir.

Side-Looking Antenna Ensures Successful Logging in Most Boreholes

Multi-Frequency Nuclear Magnetic Resonance Well Logging

Baker Atlas 1-17Formation Evaluation: Magnetic Resonance ImagingServices Catalog Version 2.1; August 2008

MREX – MR Explorer

OperationThe side-looking antenna enables the same 5-in. (12-cm) ODtool to be used in all hole sizes larger than 5 7/8 in. (149 mm)Unlike previous generation MR tools, there are no loggingspeed reductions in either large or small boreholes with theMREX service. The instrument runs eccentered in the well-bore, and therefore, is well-suited for logging deviated wells.

The MREX tool’s 2.2-in. (5.6-cm) minimum depth of investigation is deep enough to provide valid NMR data inrugose boreholes and in the presence of mudcake. Multiplefrequency operation supports multiple NMR data acquisitionssimultaneously during a single logging pass.

HighlightsA side-looking antenna and a gradient magnetic fieldyield clear readings regardless of mud conductivity, holesize or inclinationMultiple-frequency operation supports multiple, simultaneous NMR experimentsNew NMR acquisition techniques improve NMR dataaccuracy and provide superior hydrocarbon typing andfluids analysisObjective Oriented Acquisition (OOA) simplifies planning and execution of MREX logging jobsCan conduct multiple NMR data acquisitions in a single run

BenefitsReduces uncertainty in formation evaluationIdentifies hydrocarbons that may be missed by other logging technologiesReduces rig cost for acquiring NMR logs

Specifications

The MR ExplorerSM (MREX) service from Baker Atlasprovides improved data quality and logging efficiencyover previous nuclear magnetic resonance (NMR) systems. This newest-generation magnetic resonancelogging service measures porosity and permeabilityand characterizes reservoir fluids more quickly andmore accurately than previous NMR systems.



Diameter 5 in. 127 mm




The MREX side-looking magnet/antenna measures a 120º arc from an eccentered positionin the wellbore.

MREX Sensitive

Volumes

8"

Borehole

12"

Borehole

4.4"

2.4" 2.0"Formation

MREX

High-Efficiency Logging

Baker Atlas1-18 Formation Evaluation: High-Efficiency Logging Services Catalog Version 2.1; August 2008

The economic pressures of today’s drilling environment require a new approach to wireline formation evaluation that:

Reduces total job cost by minimizing rig timeMaintains the highest standard in data accuracy

Baker Atlas developed and built the FOCUS logging system for wells where rig time for logging is a major concern, and where evaluation and analysis needs can be met using the new suite of high-efficiency logging tools. FOCUS is the latest in high-efficiency, premium openhole logging systems.All of the downhole instruments have been redesigned, incorporating advanced downhole sensortechnology into shorter, lighter and more-reliable logging instruments capable of providing formationevaluation measurements with the same precision and accuracy as the industry’s highest-quality sensors — at much higher logging speeds. Logging speeds are up to twice the speed of conventionaltriple-combo and quad-combo logging tool strings. The logging system consists of the four standardmajor openhole measurements (resistivity, density, neutron, acoustic) plus auxiliary services.

More in-depth information for each application is available in the Baker Atlas FOCUS brochure.Please contact your local customer service representative, or log on to www.bakeratlasdirect.com formore information and a complete list of Baker Atlas services.

Section Contents/Solution Highlights

Focus High-Efficiency Logging

FOCUS High-Definition Induction Log (F_HDIL) Advanced resistivity array for a more accurate Rt and Rxo with patented 1D Inversion processing

FOCUS Digital Acoustilog (F_DAL) Monopole array acoustic Accurate compressional slowness (Δt) using depth-derived borehole compensation (DDBHC)

FOCUS Compensated Z-Densilog (F_ZDL) and FOCUS Compensated Neutron (F_CN) Nuclear porosity Reliable, improved accuracy at high logging speeds

FOCUS Gamma Ray Log (F_GR) Gamma ray Correlation at high speeds

Advanced Resistivity Array for More Accurate Rt and Rxo

Wellsite Efficiency and Data Accuracy

Baker Atlas 1-19Formation Evaluation: High-Efficiency LoggingServices Catalog Version 2.1; August 2008

F_HDIL – FOCUS High-Definition Induction Log

OperationThe FOCUS HDIL instrument is a multi-receiver, multi-frequency induction device. Multiple receivers provide formation resistivity information at several depthsof investigation.

HighlightsArray Resistivity – includes real time 1-D radial inversionprocessing for more accurate measurements of Rxo and Rt.Superior measurements in deeply invaded formations Detailed evaluation of the drilling fluid invasion profile Inversion processing provides a thorough analysis ofpotential reservoir zonesShort, lightweight logging instruments save rig time byreducing the rathole needed for loggingPremium sensors are designed to log at high loggingspeeds (60 ft/min, 18 m/min) reducing rig logging timewithout reducing accuracy or precision

BenefitsLatest technology ensures highest accuracySignificant rig time savings over older logging systems

Specifications

The FOCUS HDILSM instrument is designed to have a better signal-to-noise ratio than other comparableinstruments in the marketplace. Data quality is enhancedthrough high data redundancy, appropriate skin-effectcorrections and flexible post-log processing. These features result in superior data accuracy and consistentlog quality. The 1-D radial inversion processing providedwith the FOCUS HDIL data offers reliable estimates ofRt and Rxo, even in deeply invaded formations.







Comparison plot of standard conventional measurements to FOCUS measurements for High-Definition Resistivity, Acoustilog services

FOCUS High-Definition Induction Log (HDIL)/Gamma Ray (GR)/Tension, Temperature, MudResistivity (TTRMA) log presentation

X100X200

X600


Accurate Compressional Slowness (Δt)

F_DAL – FOCUS Digital Acoustilog


Formation Evaluation: High-Efficiency Logging

OperationThe FOCUS Digital Acoustilog instrument acquires high-resolution waveform acoustic data in open and cased holes. Instrument efficiently and accurately records compressional travel times using an array of downholetransmitters and receivers.

AVAN provides an approach to acoustic data acquisitionthat is “hands off,” removing the influence of surface setupover data quality, thus reducing the opportunities for acquisition error and enhancing reliability.

HighlightsAcoustic slowness – offers an improved monopole signalresulting in accurate compressional slowness values (delta t)using a depth-derived borehole compensation techniqueAccurate and efficient wellsite determination of compressional travel time (delta t)AVAN processing improves compressional slowness accuracy and reliabilityPremium sensors are designed to log at high loggingspeeds (60 ft/min, 18 m/min) without reducing accuracyor precision

BenefitsLatest technology ensures highest accuracySignificant rig time savings over older logging systems

Specifications

The FOCUS Digital AcoustilogSM (DALSM) service utilizestransmitter and receiver technologies and design elementsfrom Baker Atlas’ XMACSM instrumentation, an instrumentacknowledged in the E&P industry as the premieracoustic technology. Consistent data accuracy at thewellsite is maintained using Baker Atlas’ proprietaryAVAN processing. This calculates an accurate real-timecompressional slowness (delta t) with the option ofshear slowness in suitable formations.


Length 8.1 ft 2.5 m





FOCUS Acoustilog (DAL)/Gamma Ray (GR)/Caliper Log (CAL) log presentation

Comparison plot of standard conventional measurements to FOCUS measurements for High-Definition Resistivity, Acoustilog services

X200X300

X600


Reliable, Improved Accuracy at Higher Logging Speeds

F_ZDL – FOCUS Compensated Z-Densilog



OperationThe FOCUS Compensated Z-Densilog instrument possesses features that enhance quality including scintillation detectors,256-channel spectrum recording, real-time compensation fortemperature and bulk-density changes.

HighlightsNuclear porosity – design changes improved detector response and efficiency at high logging speeds compared to conventional instrumentsAccurate determination of gas zonesPremium sensors are designed to log at high logging speeds(60 ft/min, 18 m/min) without reducing accuracy or precisionNew articulation design and reduced pad size maintains padcontact much better than conventional instrumentsTwo FOCUS ZDL tools combinable in tandem at 90° to eachother for accurate ZDL logging in severe borehole conditions.

BenefitsAccurate measurements reduce uncertainty in formation evaluationReduced cost of operations achieved by shorter tools andfaster logging speeds

Specifications

The mechanical and sensor limitations of previous instruments were overcome in the designing and building of the new FOCUS Compensated Z-DensilogSM (ZDLSM)instrument. The mechanical design of the FOCUS ZDLinstrument provides excellent pad contact with the boreholewall at high speeds even across rugose boreholes andthrough washed out zones. The pad design is shorter thanon other typical instruments with articulation that providesmaximum flexibility. The result is high-confidence densityporosity data in a wider range of borehole conditions, evenat high logging speeds.


Length 9.6 ft 2.9 m




Weight 200 lb 90.7 kgComparison plot of standard conventional measurements to FOCUS measurements for Z-Density, Compensated Neutron and Gamma Ray services

FOCUS Compensated Z-Densilog (ZDL)/Compensated Neutron (CN)/Gamma Ray (GR)/Caliper (CAL) log presentation

X200X300

X100


Reliable, Improved Accuracy at Higher Logging Speeds

F_CN – FOCUS Compensated Neutron



OperationThe FOCUS Compensated Neutron instrument utilizesa source and two detectors to help identify porous formations and estimate porosity.

HighlightsNuclear porosity – design changes improved detectorresponse and efficiency at high logging speeds ofconventional instruments, and enabled production ofa real-time nuclear porosity cross-plot logAccurate determination of formation porosityAccurate determination of gas zones (when combinedwith Compensated Densilog and/or Acoustilog)Premium sensors are designed to log at high loggingspeeds (60 ft/min, 18 m/min) reducing rig loggingtime without reducing accuracy or precision

BenefitsLatest technology ensures highest accuracySignificant rig time savings over older logging systemsShort, lightweight logging instruments save rig timeby reducing the rathole needed for logging

Specifications

The FOCUS Compensated Neutron instrumenthas been extensively modeled to provide repeatableaccuracy with high confidence in reservoir rocksand formations exhibiting a high porosity. Designchanges improved detector response and efficiencyat high logging speeds of conventional instruments,and enabled the production of a real-time nuclearporosity cross-plot log.


Length 4.8 ft 1.5 m





Comparison plot of standard conventional measurements to FOCUS measurements for Z-Density, Compensated Neutron and Gamma Ray services

FOCUS Compensated Z-Densilog (ZDL)/Compensated Neutron (CN)/Gamma Ray(GR)/Caliper (CAL) log presentation

X200X300

X100


Correlation at High Logging Speeds

F_GR – FOCUS Gamma Ray Log



OperationPremium sensors are designed to log at high logging speeds(60 ft/min, 18 m/min) without reducing accuracy or precision.

The single, most-critical measurement made during a wirelinelogging run is the depth measurement. Even small errors inthe depth estimate can corrupt data such as syntheticallyfocused resistivity curves. The assumption that the loggingtool is moving smoothly through the borehole is not usuallyvalid due to rugose and sticky borehole conditions and theeffect of centralizers and decentralizers in the toolstring. Anaccelerometer aligned along the long axis of the toolstringcan be used to make corrections to the surface depth estimate.

HighlightsMake depth correlation with other logsDetermine stratigraphic profilesEstimate shale content in reservoir rocksDelineate stratigraphic boundariesPremium sensors are designed to log at high loggingspeeds (60 ft/min, 18 m/min), reducing rig logging timewithout reducing accuracy or precision

BenefitsLatest technology ensures highest accuracySignificant rig time savings over older logging systemsShort, lightweight logging instruments save rig time byreducing the rathole needed for logging

Specifications

The FOCUS Gamma Ray has been redesigned to logat the higher rates of the FOCUS system. It includes aninline accelerometer which is used to correct for stickand pull.


Length 8.0 ft 2.4 m





FOCUS Compensated Z-Densilog (ZDL)/Compensated Neutron (CN)/Gamma Ray (GR)/Caliper (CAL) log presentation

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Baker Atlas1-24 Formation Evaluation: Geological Services Services Catalog Version 2.1; August 2008

Geological Services

Borehole images and high-resolution formation dip data describe the structural framework, fracture patterns,sedimentary features and in-situ stress orientation of the formation. Borehole images and resistivity anisotropymeasurements provide valuable information to design completion and perforation strategies. These measurementsare used as an aid in conventional core description and orientation, as well as for selecting intervals for formationtesting, sampling and perforating.

For thinly laminated sequences, borehole images and resistivity, anisotropy measurements are the only practicalmethod of determining net-pay thickness in the absence of conventional cores. In addition, these services areused for the identification of bioturbated zones, overturned, slumped, and contorted beds — all potential impediments to production. When combined, the horizontal and vertical resistivities from the 3DEXSM serviceand the high-resolution borehole images from the STAR ImagerSM or the EARTH ImagerSM services can significantly improve the petrophysical evaluation of thinly bedded sand-shale sequences.

More in-depth information for each service is available in the Baker Atlas Borehole Imaging Services andApplications manual and the HDIPSM brochure. Please contact your local customer service representative, or logon to www.bakeratlasdirect.com for more information and a complete list of Baker Atlas services.


Technology

Imagers STAR Imager EARTH Imager Digital Circumferential Borehole Imaging LogHexagonal DiplogWell Geometry Instrument

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Baker Atlas 1-25Formation Evaluation: Geological ServicesServices Catalog Version 2.1; August 2008

Micro-Resistivity Imaging for Wells Drilled with Water-Based Muds

STAR Imager – Water-Based Mud Formation Resistivity Imager

High-Resolution Formation Imaging

OperationThe six-arm independently articulated carrier and poweredstand-off ensures optimal sensor-to-formation contact evenin highly deviated boreholes. Pads with 24-sensors aremounted on each of the six articulated arms, producing atotal of 144 microresistivity measurements, with a verticaland azimuthal resolution of 0.2" (~5 mm) resulting in thehigh-resolution borehole images described above.

The STAR Imager service may be logged in combinationwith the acoustic imager (CBILSM) service to provide complementary measurements allowing for a more completeevaluation of the formation.

HighlightsStructural analysis including structural dip analysis, faultand fold analysis and unconformity recognitionFracture evaluation Sedimentological analysis including description of faciesand facies sequences, determination of paleotransportdirection, analysis of reservoir geometry and characteri-zation of depositional environmentNet-to-gross analysisUsed with 3DEXSM service for quantitative thin-bed analysisAllows for determining reservoir permeability trends

BenefitsOptimizes development well placement and hydrocarbondepletion efficiencyHelps differentiate open from closed fractures for production analysis

Specifications

The STAR ImagerSM service provides high-resolutionresistivity formation images in conductive mud systemsused to identify geological and borehole features.These include planar features such as bedding, fracturesand faults, and stratigraphic features such as cross-bedding and ichnofabrics, in addition to borehole wallfeatures such as breakout and drilling-induced fracturing.The identified features are subsequently used in theanalysis of structural dip, fracture systems, depositionalenvironments, borehole stability and net-pay in thinlybedded sequences.

Thinly bedded deepwater sheet sands. Light/darkalternating bands on the STAR Imager log correspond to a similar outcrop analogue asshown in the photograph.

The STAR Imager tool



Diameter 5.25 in. 133 mm

Pressure Rating 20,000 psi 138 MPa


Weight 680.9 lb 310 kg

STAR Imager STAR Imager(Static) (Dynamic)

0 degrees 360 0 degrees 360

3 ft


Micro-Resistivity Imaging for Wells Drilled with Oil-Based Muds

EARTH Imager – Oil-Based Mud Formation Resistivity Imager

High-Resolution Formation Imaging

Formation Evaluation: Geological Services

OperationThe EARTH Imager service uses advanced electrical conductivity measurements in oil-based mud systems toprovide high-resolution image logs of a quality previouslyavailable only in water-based mud systems. The EARTHImager service allows simultaneous acquisition of high-resolution resistivity and acoustic borehole image data. This unique capability provides a powerful interpretationperspective based on two sets of complementary data.

The EARTH Imager service incorporates a microresistivityimaging and focusing technique into a field-proven carriermechanism that affords operators the unique ability to logimages in horizontal, highly deviated and rugose wells.

HighlightsStructural analysis including structural dip analysis, faultand fold analysis, and unconformity recognitionFracture evaluation Sedimentological analysis including description of facies, determination of paleotransport direction andcharacterization of depositional environmentNet-to-gross analysisUsed with 3DEXSM service for quantitative thin-bed analysisAllows for determining reservoir permeability trends

BenefitsOptimizes development well placementAllows easier and more confident interpretations byresolving finer vertical and azimuthal featuresHelps differentiate open from closed fractures

Specifications

The EARTH ImagerSM service from Baker Atlas bringsthe well-understood responses of microresistivityimages in wells drilled with non-conductive (commonlyreferred to as oil-based) muds. This service providessignificantly improved vertical resolution and boreholecoverage when compared to other available systems.Detailed structural, sedimentological and petrophysicalanalysis using image data is now possible in wellsdrilled with oil-based muds.




Pressure Rating 20,000 psi 138 MPa25,000 psi 172 MPa



The EARTH Imager tool

The EARTH Imager service provides high-resolution borehole images in wells drilledwith oil-based mud.

EARTH Imager EARTH Imager“Static” Normalization “Dynamic” Normalization



Borehole Ultrasonic Images in All Mud Types

CBIL – Circumferential Borehole Imaging Log

High-Resolution Borehole Imaging


A CBIL log example of overturned folded beddingwhere reservoir navigation is highly problematic.Information such as fold axis and the dip of thefold limbs are not normally available from othersources. Fractures are also clearly visible on this image.

The CBIL Imager tool OperationFull 360°-borehole imaging is possible due to an acoustictransducer operating in the pulse-echo mode. The transducerrotates to scan the entire circumference of the borehole wallproviding sharp images and boundary delineation.

The CBIL instrument operates reliably in both water-basedand oil-based muds. The lower operating frequency (250 kHz)allows for superior performance in larger holes and heaviermuds than other similar devices. Because the CBIL systemis an acoustic device that does not require contact with theborehole wall, it is quite effective in horizontal wells. Itssmall size [3.625 in. (92.1 mm)] allows for operation in slimholes as well as large-diameter holes. Signature waveformrecording allows the image data to be monitored real timeduring acquisition.

HighlightsPresents a complete 360°-borehole imageDetermination and orientation of formation dipIdentify and classify faults and unconformities Detect secondary porosity – fractures, vugs, and washouts Determine sand/shale distributions in thin-bed sedimentary sequencesImages facilitate detailed sedimentological analyses

BenefitsDetermine optimum kick-off direction for horizontal drilling Plan well-site positioning for production optimizationStructural dip analysis improves inter-well correlation andrefines structural interpretation

Specifications

The digital Circumferential Borehole Imaging LogSM

(CBILSM) system provides high-resolution boreholeimages in difficult wellbore conditions including high-porosity, unconsolidated formations. These images provide valuable insight for making difficult drilling,completion and production decisions at the wellsite.







CBIL CBIL(Static) (Static)



Detailed Structural and Stratigraphic Dip Evaluation

HDIP – Hexagonal Diplog

High-Resolution Formation Dip Information









OperationA tri-axial accelerometer and three magnetometers are employed to determine borehole drift and azimuthand correct for velocity fluctuations of the instrument.Accurate borehole geometry and wellbore volumes are determined from the six independent caliper measurements.

This instrument can host measuring pads suitable forwater-based mud or oil-based mud systems.

HighlightsGeological structural and stratigraphic dip evaluation Detailed geologic evaluation across target reservoirs Improved dip data acquisition in highly deviatedand horizontal wells (using an innovative powered standoff)Determination of sand/shale distribution in thinly bedded sediments Six-point evaluation of borehole size, geometry and integrated borehole volumeFracture identificationDirectional surveys

BenefitsDetermine offset locations based on structural dipMap field perimeters and bed thicknesses for accurate reserve calculations


The Hexagonal DiplogSM (HDIPSM) logging serviceacquires high-resolution formation dip informationusing six independent microresistivity sensors. TheHDIP data is processed to calculate and orient thedip and direction of formation features. Theprocessed dip values can then be correlated to thestructural and/or stratigraphic geologic events thatgenerated them.


High-resolution and Versatile Six-arm Caliper Measurement Service

WGI – Well Geometry Instrument

Continuous Profile of the Wellbore


Operation

As part of formation-evaluation programs in all explorationand development wells, a large variety of caliper instrumentsare used either as stand-alone devices or in combinationwith other measurements. The WGI measurement serviceaddresses the most significant shortcomings of previouscaliper tools: high-resolution calipers cannot acquire datawhile running in the hole, and instruments designed to work in both directions do not acquire measurements withhigh-enough resolution.

FeaturesCan acquire data in both upward and downward directionsThe small contact area of the caliper measuring tipsallows high-resolution measurements Can be run simultaneously with an orientation instrumentat all sample ratesCombinable with all other openhole instruments in anystring configurationBrings significantly improved vertical and azimuthal resolution when compared to other caliper devices

BenefitsWhen logged as part of the first openhole string, the WGImeasurement service provides an early insight into thehole quality for wellsite completion decisionsFully oriented hole geometry profiles can be generated atthe wellsite to determine testing and sampling feasibility Provides accurate environmental corrections for petrophysical services reducing uncertainty in formation evaluation

Specifications

The Baker Atlas Well Geometry InstrumentSM (WGISM)measurement service brings a new dimension to open-hole caliper measurements by acquiring high-resolutiondata while running in and out of the hole.

Example of a field presentation of a 3-D-boreholeprofile acquired while running in hole using a WGI caliper in combination with the Baker AtlasReservoir Characterization InstrumentSM

(RCISM) service.

No testing or sampling attempts were made at the out-of-gauge borehole intervals, clearly visiblein the 3-D profile, saving a significant amount ofrig time.






Weight 115 lb 52 kg

A fully open mechanical section of the WellGeometry Instrument tool showing the telescoping arm design, which allows full 6-radii logging in both directions.

Reservoir Characterization InstrumentRotary Sidewall Coring ToolSidewall Corgun

2. Formation Testing and Sampling Services

II

Formation Testing and Sampling

Baker Atlas2-2 Formation Testing and Sampling

For efficient completion design, gas-, oil-, and water-bearing zones must be identified and characterized alongwith fluid contacts and hydrocarbon types. The Reservoir Characterization InstrumentSM (RCISM) service definesthe reservoir pressure profile and obtains samples of the reservoir fluid, both key elements of the completionperforating design. The RCI service’s expanded offerings include SampleViewSM IC service, Single-phase Tanks(SPT) and Straddle PackerSM module. The RCI service provides this information in real time, crucial in the decision-making process.

Laboratory testing of sidewall cores provides valuable rock characteristics used in the course of evaluating a formation. Information gathered from sidewall cores can be used throughout the life of a reservoir, fromdetermining sensitivities to formation damage during drilling, to maximizing hydrocarbon production.

Baker Atlas offers two sidewall coring services: the Rotary Sidewall Coring ServiceSM (RCORSM) service and theSidewall CorgunSM tool. The RCOR service is a computer-controlled and hydraulically powered wireline coringdevice for cutting and retrieving multiple sidewall core samples. The Corgun tool is a ballistically operatedsidewall coring system. The samples obtained help oil and gas producers better evaluate their reservoirs.

More in-depth information for each service is available in the Baker Atlas RCI RESolution and RCORbrochures. Please contact your local customer service representative, or log on to www.bakerhughesdirect.comfor more information and a complete list of Baker Atlas services.


Services Catalog Version 2.1; August 2008

Limitless Pre-Flushes and Overpressured Samples Ensure Single-Phase Samples

Obtain High-Quality Representative Formation Fluid Samples

Baker Atlas 2-3Formation Testing and SamplingServices Catalog Version 2.1; August 2008

RCI – Reservoir Characterization Instrument

OperationSample pressures in conjunction with limitless pre-flush volumes are used to monitor sample clean-up and ensure a single-phase representative formation fluid sample is captured. Sample tanks aremaintained at a positive overbalanced pressure to eliminate the risk of sample-flashing in the tanks during sampling. Captured samples are overpressured downhole to ensure a single-phase sample is transported to the surface.

The RCI instrument is a modular formation testing and sampling tooldesigned to provide a more complete description of reservoir fluidand behavior. The instrument’s modularity provides the ability to testand sample fluids in a wide range of geological environments andborehole conditions. It includes a fully controllable packer section forvariable-volume and variable-rate drawdown, large volume (500 cc)displacement pumps, a Multi-tank Carrier for cost-efficient samplerecovery, and the SampleView module, a near-infrared analyzer forcomplete downhole fluid characterization. The RCI service can alsobe configured with the Straddle PackerSM module for testing and sampling in low permeability, fractured and unconsolidated formations,as well as for conducting mini-DST and micro-Frac testing for completerock and fluid characterization. The RCI service also incorporatesFormation Rate AnalysisSM (FRASM), a proprietary technique usedwhen formation pressure testing that provides a method to validateformation pressure test data and provides a robust permeability estimate. This real-time analysis technique improves testing and sampling efficiency.

HighlightsExtensive pre-job modeling and planningPrecision, repeated pressure measurements on a single seatMultiple clean fluid samples at reservoir conditionsWell suited for fluid sampling for accurate measurement of low-level H2S concentration and formation water pH.Real-time downhole fluid assessment

Specifications – Series 1970 w/Transportable 6-Tank Carrier

The Reservoir Characterization InstrumentSM (RCISM) service with SampleViewSM module is a wireline formation pressure testing and fluid-sampling service. The RCI service provides keypetrophysical information to determine reservoir volume, forma-tion producibility, and the type and composition of the movablefluids – and to predict reservoir behavior during production.

The Multi-tank Carrier is designed to efficiently collect 24+ samples during a single trip and save rig time.







The RCI instrument can collect representative samples and eliminate the need for a Drill Stem Test (DST).

BenefitsPrecision Pressure measurements validated in real time with FRA. SmartSampling with RCI tool’s uniquedrawdown pressure control.SampleView module providesreal-time fluid characterizationwhile monitoring sample contamination levels.Up to 24+ representative reservoir fluid samples andunlimited pressures for true reservoir characterization Advanced reservoir characterization using theStraddle Packer module formini-DST and micro-Frac.

Representative Fluid Samples, Mini-DST, Interference Testing and Mini-FRAC

Straddle Packer Module

Baker Atlas2-4 Formation Testing and Sampling Services Catalog Version 2.1; August 2008

Utilizing two Baker Oil Tools custom-designed inflatablepacker elements, a one-meter zone is isolated to enable various tests to be conducted in this isolated interval. Thedifferent testing modes include basic pressure tests, high-quality single-phase samples, mini-DST, interference andmini-frac tests.

FeaturesFully combinable with all RCI modules One-meter isolated zone (variable using inserts) In-line temperature probe In-line quartz pressure crystal with zero-depth offset Standard elements cover both water- and oil-based mud systems Hole sizes: 6 in. to 14 in. (152.4 mm to 356 mm)

BenefitsPressure tests and fluid samples can now be acquired inpreviously unexplored zones, increasing confidence incompletion decisions. High-quality test data save completion costs by avoidingbad zones or increase profits by completing previouslyby-passed commercial zones.High-quality, single-phase samples at in-situ conditionsprovide insight to properly plan future completion andfacilities designs.Mini-frac tests optimize frac designs saving frac horse-power expenses while still exploiting the full productionpotential of the reservoir.

The Straddle PackerSM module is a recent addition to theBaker Atlas’ Reservoir Characterization InstrumentSM

(RCISM) suite of modules. The Straddle Packer addressesthe limitations generally encountered in low perm, fractured, vuggy and unconsolidated formations.

Expansion of the Reservoir CharacterizationInstrument service with Straddle Packer technology is continuing with the development of small-scale Drill Stem Test (mini-DST) andinterference testing.

The top figure shows an example of a mini-DSTtest result where the Straddle Packer build-uppressure response is plotted logarithmically withits derivative to demonstrate the detection of bothspherical and radial flow regimes.

The bottom figure shows an example of a mini-DST complete with interference test. As shown in the example, the Straddle Packer pressureresponse is combined with a remote referenceprobe response or interference test.

The remote probe response is used to verify theStraddle Packer response and to help resolveboth horizontal and vertical permeabilities in situations where radial flow might not be present.

Improves Downhole Fluid Characterization

SampleView IB Service


The original SampleView optical analyzer has beenupgraded to improve resolution and stability to aid in thedevelopment of chemo-metric modeling. Additionally, twooptical channels have been added to identify and quantifythe presence of methane (Figures 1, 2).

With improved SampleView IB optical response, BakerAtlas has introduced the FTAForecast software. This real-time software allows the engineer to calculate an estimationof sample purity at individual depths (Figure 3). The softwareenables selection from the full range of SampleView-acquiredmeasurements as inputs to the analysis, and graphically displays the estimations of sample purity at any given depth.

Refractive Index

A measurement of Refractive Index in the SampleView IBservice aids in the identification of fluid types and contami-nation monitoring. This continuous measurement allows forvery accurate OBM filtrate contamination monitoring andgas presence. The refractive index of various fluid types issignificantly different, allowing simple differentiationbetween gas, oil and water. The refractive index can also be used as an input to the FTAForecast analysis.

Fluorescence Spectrometer

The SampleView IB service also has a fluorescence spectrometer. Through use of a downhole ultraviolet lamp, a measurement of hydrocarbon fluorescence is acquiredover five differing wavelengths. This measurement aids inthe hydrocarbon typing process based upon fluorescencespectrum, and differentiation between light crude oils andcondensates (Figure 4).

In-situ Phase-separation Measurements

The ability of the RCI tool to perform phase-separation tests under downhole conditions has been incorporated intothe FTA software package available with the SampleView IBservice. This allows for real-time estimations for compress-ibility of the fluid and gas states while performing a phase-separation test, plus built-in algorithms for indicating thephase-separation pressure measured downhole at reservoirtemperature and pressure (Figure 5).

Baker Atlas has improved the technology for acquiringrepresentative formation fluid samples. SampleViewSM

IB service, introduced as a significant upgrade to theoriginal Reservoir Characterization InstrumentSM (RCISM)SampleViewSM module, brings enhanced fluid character-ization measurements to better quantify fluid typing and contamination.

Fig. 1 - SampleView spectrum of 38API crude oil withmethane channels highlighted

Fig. 2 - Spectrum of methane channels through clean-upperiod, allowing estimation of gas/oil ratio based on thecalculated weight fraction of methane present

Fig. 3 - Example of FTAForecast analysis using opticalabsorbance as primary input

Fig. 4 - Light crude oils have a more intense fluorescencein the lower wavelengths.

Fig. 5 - Phase-separation test performed downhole underreservoir temperature and pressure for automatically calculating bubble-point pressure and compressibility offluid and gas phases

Fig. 5

Fig. 3

Fig. 4

Fig. 2

Fig. 1

SampleView IC Service


FeaturesFluid density and viscosity sensorAcoustic transducer for measuringfluid sound speed19-channel real-time near infraredspectrometer (includes 2-channelmethane detection)Continuous refractometer5-channel UV fluorescence spectrometer

BenefitsAccurate in-situ measurement offluid properties provides efficientreservoir fluid characterizationAccurate GOR predictionReliable determination of compo-sitional grading based on multipleclosely spaced fluid propertiesmeasurementsReliable sample contaminationmonitoring to ensure high-qualitysamples are captured for labanalysis.Validation of PVT results from lab analysis of collected samplesby comparison with in-situ measurements

SampleView IC module is rated to350° F (177° C) and 20,000 psi(137.9 MPa) and is fully combinablewith all RCI modules.

The SampleViewSM IC module isa service offering from Baker Atlasthat represents a significantadvancement in downhole reservoir fluid characterizationbecause it provides a continuousreal-time measurement of density,viscosity and sound speed of thereservoir fluid. These accuratemeasurements, combined withthe fluid pressure and temperature,are used to calculate solutiongas-oil ratio in real time.

Example of the enhanced real-time interpretation log available withSampleView IB and IC modules. Real-time fluid fraction determination combined with image displays of optical absorbance, fluorescence and refractive index all aid the identification and monitoring of fluids during theclean-up and sampling process. In addition, SampleView IC service providesphysical properties such as Fluid Density, Fluid Sound speed and GOR forefficient reservoir fluids characterization.

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RCI Single-phase Tanks


Single-phase I sampling is similar to PVT sampling with an addedfeature to further compensate for the sample cooling as it is retrievedfrom the wellbore. The RCI Single-phase I Tank consists of twofloating pistons with a pre-determined charge of nitrogen betweenthe pistons. Expansion of the nitrogen gas compensates for thepressure drop in the sample due to temperature loss as the sampleis retrieved from the well and transported to the lab.

Single-phase I tanks can be outfitted with the Baker Atlas ContinuousData Recorder (CDR) to monitor sample integrity during transport.These tanks incorporate mixing balls (a requirement from the PVTlabs) and have U.S. Department of Transportation and CanadianTransit Authority exemptions, so they can be transported by common carrier. The tanks are rated for 20,000 psi (137.9 MPa),400° F (204° C), and are constructed from NACE-approved materials. Single-phase II sample chambers are designed to capture 432 cc samples up to 25,000 psi (172.4 MPa).

The Single-phase II sample (SPT II) is also appropriate when an accurate determination of PVT parameters is required and forflow-assurance studies and the conditions warrant additional compensation over the Single-phase I sample. Single-phase II sampling is recommended when reservoir conditions exceed 250° F(121° C) or 13,000 psi (89.6 MPa). It is particularly suited to sampling in black oils, high-GOR volatile oils, and retrograde condensates. It is also recommended for formation water sampling.

Single-phase II sampling is similar to Single-phase I samplingwith an added feature to further compensate for the sample coolingas it is retrieved from the wellbore. The RCI Single-phase II Tankconsists of two floating pistons with a pre-determined charge ofnitrogen behind the second piston.

The nitrogen piston has a 2:1 compression ratio, which effectivelydoubles the compensation potential in the tank.

Single-phase II Sample Tanks also features two 15 cc MicroSampleTanks that can be extracted to validate the samples without disturbingthe main sample chamber.

The tanks are rated for 25,000 psi (172.4 MPa), 400° F (204° C),and are constructed from NACE-approved materials.

Single-phase I sample chambers are designed to capture a 450 cc sample. The Single-phase I sample is appropriatewhen an accurate determination of PVT parameters is requiredand for flow-assurance studies. These chambers are particularlywell suited to sampling in black and volatile oils. They are alsorecommended for formation water sampling because ideally,the sampling process maintains the integrity of dissolvedgases such as H2S or CO2 and other dissolved minerals, thusmaintaining the pH of water at in-situ conditions. Accuratedetermination of formation water pH, in turn, allows for deter-mining scaling potential. The RCI Single-phase I Tank systemswere specifically designed to maintain sample integrity byeliminating the need to combine smaller volume samples inorder to obtain a sufficient volume for PVT analysis.

Single-phase I Tank

Single-phase II Tank

RCI Multi-tank Carrier


Baker Atlas offers two multi-tank carrier modules with the RCISM

service, a 6-tank carrier for efficient multi-zone sampling and a 2-tankcarrier which is purpose-built for HPHT single-phase sampling.

Features of the 6-Tank Carrier:Six tanks per module840 cc PVT sample tanks or 450 cc Single-phase I TanksUp to 24 tanks per run with power boosterIntegral borehole exit

Traditional wireline formation test tools are capable of taking onlytwo formation fluid samples. The Multi-tank module houses sixtanks, and up to four modules can be combined on a single trip intothe hole. This feature allows the combination of 26 tanks in a singleRCI instrument run, including the two standard large-volume 4-, 10-or 20-liter sample tanks. This configuration provides the largest possible quantity and volume in the industry. The integrated boreholeexit eliminates the need to include a Borehole Exit Module when theMulti-tank Carrier is being run.

The RCI instrument uses hydraulic sealing valves on each tank,which can be positively verified by pumping against the valve toensure that sample integrity is maintained.

Features of the 2-Tank Carrier:Two tanks per module432 cc Single-phase II Tanks with integral micro-sample chambersUp to four tanks per run with power booster

The two-tank carrier with SPT II sample tanks is another option thatcan be selected when configuring the RCI instrument for samplingoperations. Using this option, the RCI tool can collect a total of sixsamples per run in hole (4 x DOT tanks + 2 x large volume tanks).All tanks can be overpressured to reduce the possibility of phase sepa-ration during sample retrieval to surface. The value of the requiredoverpressure is determined during the pre-job planning and con-firmed in real time with a downhole expansion test.

Service Application Up to 24 Single-phase I or PVT samples in any combination pertrip in the well Up to four single-phase II samples per trip in the well 6-tank carrier is fully combinable with 2-tank carrier and high-volume sample tanks

Benefits Multiple samples per trip in a well in any combination and unlimitedpressure measurements provide true reservoir characterization. Representative sampling for a wide range of reservoir conditions.

The Multi-tank Carrier is designed to efficiently collect multiplesamples during a single trip into the well. This process yieldscost-effective, high-quality sampling and a significant savings in rig time.

Preserve Rock Properties, Avoid Damages Caused by Percussion Coring

RCOR – Rotary Sidewall Coring Tool

Obtain High-Quality Representative Formation Core Samples

Baker Atlas 2-9Formation Testing and Sampling: Coring ServicesServices Catalog Version 2.1; August 2008

OperationThe RCOR system can drill multiple core samples fromdownhole formations and store them in the core-storage section of the tool body for retrieval back to the surface.The sidewall cores are drilled using a pivoting bit box. Asthe tool is lowered into the hole, the bit box is in-line withthe tool body. At the desired depth, the bit box is pivotedinto the drill position to make contact with the wellborewall. The maximum retrievable core length is then drilled,measured, and stored. The tool can then be repositioned forthe next sample. A maximum of 60 cores per trip areachievable with the RCOR system.

HighlightsBuild reservoir description with information about formation lithology and petrology Evaluate storage capacity (porosity) and flow potential (permeability) Analyze hydrocarbon type and content Measure irreducible water content Identify thin producing intervalsCore recovery in horizontal wellsHard-rock formation samplingPositive core acquisition indication

BenefitsAcquisition of undamaged sidewall cores suitable forporosity and permeability analysis Enhanced measurement of formation and reservoir fluidparameters for reservoir and production applicationsCost-effective alternative to conventional coring saves rigtime and money


The Rotary Sidewall Coring (RCORSM) instrument provides the ability to acquire undamaged sidewall coresamples suitable for porosity and permeability analysis.The RCOR system is an advanced, computer-controlledand hydraulically powered coring device for cutting andretrieving multiple sidewall cores. The entire coring andstorage operation is continuously monitored by meansof a graphical surface system.

Bit section of Rotary Sidewall Coring Tool







Confirm Paleontology and Hydrocarbon Shows in Zones of Interest

SWC – Sidewall Corgun

Efficient Acquisition of Core Samples

Baker Atlas2-10 Formation Testing and Sampling: Coring Services Services Catalog Version 2.1; August 2008

OperationThe operating principle of the SWC instrument is relativelysimple. A core barrel, which is a hollow cylinder, is shotinto the formation by a powder charge ignited by an electriccurrent. The core barrel, containing a formation sample, isretrieved by means of a steel cable attached between the gunand the core barrel. Only one core barrel is fired at a time.A tandem gun can selectively core up to 50 samples on asingle run using the 4 in. (101.6 mm) SWC tool and up to44 samples on a single run using the 3 in. (76.2 mm) SWCtool. The SWC tool can collect a maximum of 74 cores byrunning three SWC tools in tandem.

Core barrels are available to sample formations ranging fromsoft to very hard. The core samples are generally large enoughto allow a comprehensive core analysis. Cores range in sizefrom 0.85 in. (21.6 mm) to 0.69 in. (17.5 mm)

The SP or gamma ray curve, run simultaneously with theSWC tool, provides depth correlation with the primary suiteof logs.

HighlightsPaleontological dating (microfaunal/microfloral and spore content) Determine or confirm hydrocarbon shows

BenefitsCost-efficient acquisition of core samples suitable forhydrocarbon and lithology confirmation Up to 50 cores can be acquired in a single trip using standard guns


Conventional methods of coring are used during thewell-drilling operation. Often, however, formation coresare desired after the total depth is drilled and the basicopenhole logs are complete. The Sidewall CorgunSM

(SWCSM) tool provides a means for recovering a depth-specific sidewall formation sample suitable for hydrocarbon and lithology confirmation.








Borehole Seismic ApplicationsDownhole InstrumentationSurface InstrumentationVSFusion Borehole Seismic Processing

3. Geophysical Services

III

Geophysical Services

Baker Atlas3-2 Geophysical Services Services Catalog Version 2.1; August 2008

Borehole seismic applications and services are an essential part of energy exploration. With a seismic receiverplaced in the earth at depth and an energy source on the surface, accurate time-depth measurements are producedthat can be used to calibrate well logs. By changing the location of surface sources and the number of receiversin the borehole, high-resolution data can be recorded and detailed formation properties and reservoir images canbe produced. Providing high-resolution data enables 3-D images to be created which can improve vertical andlateral resolution of the reservoir when compared to surface seismic data. Baker Atlas’s borehole seismic divisionprovides the latest in digital data acquisition systems and services, which provide clients with quality data andproven results.

VSFusion – Baker Hughes’ joint venture with CGG-Veritas is an industry leader in borehole seismic processing.VSFusion provides a full spectrum of borehole seismic application design, data processing and interpretation.VSFusion’s 3-C 3-D vector migration processing can provide the most accurate structural image possible byprecisely locating each reflection point in the VSP data. VSFusion also provides leading technology in processingand interpretation of 3-D VSP data.

Magnitude – Baker Atlas microseismic experts, use the latest technology in seismic processing of acousticevents in microseismic monitoring and hydraulic fracture mapping. Hydraulic fracture mapping is achieved bymonitoring and recording microseismic events that occur during the fracture treatment of a well. Fracture moni-toring provides an independent estimate of fracture volume and direction which is crucial to the optimization ofa prospects development program. Baker Atlas provides the latest technology in digital downhole equipmentand wellsite operations while Magnitude provides processing and interpretation of the microseismic data.


Primary Application

Single Level RecieverMulti-level Reciever Slimhole RecieverPipeSies** Borehole seismic acquisition inside drillpipe

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Borehole Seismic Processing

Process Objective

2-D Imaging Improve resolution and depth prediction3-D Migration Delineation of reflectors and faults3-C, 3-D Migration Enhancement of 3-D image effects4-C Processing Separation of wavefields in horizontal wells for improved imaging below the well3-D VSP Processing High-resolution structural imagingQ-Compensating Surface Seismic Data Restore lost bandwidth to surface seismic data3-D VSP Inversion Improves vertical resolutionPre-survey Modeling Positioning of VSP recievers to maximize survey resultsPost-survey Modeling Updates pre-survey modeling to best match VSP dataMicroseismic Events Hydraulic fracture mapping

Application: Time-Depth Correlation

Velocity Survey

Borehole Seismic Applications

Baker Atlas 3-3Geophysical Services: Borehole Seismic ApplicationsServices Catalog Version 2.1; August 2008

Velocity or Checkshot Survey

Velocity Survey Table

OperationVSFusion provides calibration information and parametersderived from borehole seismic measurements to enhancesurface seismic imaging, attribute processing, and reduceduncertainty in surface seismic interpretation.

The Velocity Survey uses a combination of geophysical andwell logging techniques to measure the one-way travel-timeof a seismic pulse. This pulse is generated from an energysource, located at ground or sea level, and propagates to ageophone receiver placed at a known depth in the borehole.Using the measured total travel-time for a measured depth,the average velocity of a pulse propagating through theearth to that depth is calculated and corrected to the seismicdatum. Interval velocities are calculated between check shotlevels. By comparing acoustic well log integrated intervaltimes to the measured one-way seismic travel-times fromthe Velocity Survey, the acoustic log values can be adjustedfor errors due to borehole conditions such as borehole diameter, drilling fluid invasion and formation gas.

HighlightsWell log and surface seismic time-depth correlationDriller’s depth and surface seismic time-depth correlationVelocity analysisWell log editingSynthetic seismogram generationWell log conversion to time scale

BenefitsVelocity analysis – stacking and migration velocitiesWell log and surface seismic time-depth correlation

Travel-time measurements are acquired with receiversplaced at known depths in a well. These measurementsproduce accurate time-depth and seismic velocityresults that can be used to calibrate well log data.Velocity survey information is presented as time-depthcorrelation plots and detailed velocity tables. Boreholeseismic-generated velocity information is used to calibrate acoustic well log data and produce accuratesynthetic seismograms. Synthetic seismograms link surface seismic time-domain information with high-resolution, depth-domain well log data.

Zero Offset Vertical Seismic Profile (ZVSP)

Baker Atlas3-4 Geophysical Services: Borehole Seismic Applications Services Catalog Version 2.1; August 2008


Application: True Wavelet, Phase and Multiple Identification

Zero Offset VSP

OperationWith a zero offset VSP, the energy source is placed a relatively short distance from the well. The downholereceiver spacing is usually denser than that used whenrecording a velocity survey. In addition to measuring theelapsed time for the surface-activated energy source pulse to travel to the geophone, as is done with a velocity survey,the VSP technique is used to record and interpret the seismic response that follows the first arrival pulse.

The primary output from the zero offset VSP is a singlestacked trace, which represents the acoustic response of thesubsurface at the well location. This single trace, consistingof primary reflections called the corridor stack trace, iscompared to the surface seismic data at the well location.The VSP receiver is placed downhole rather than on the surface to provide the following benefits:

HighlightsImproved time-depth relationshipTrue wavelet corridor stackMultiple free corridor stackIdentify surface seismic events as primary reflection ormultiple reflectionsIdentify depth at which seismic event intersects wellboreDepth prediction of seismic events ahead of the drill bitImproved vertical resolution compared to surface seismic dataWavelet extraction and wavelet shapingPhase determination and matching of surface seismic dataComplex structure and wellbore deviation to allow foroffset imaging with improved lateral resolutionAttenuation studies (Q estimation)Extraction of parameters for enhanced surface seismic processing

BenefitsMeasured averaged and interval velocities and improvedtime-depth relationship Identify surface seismic events as primary reflections ormultiple reflections

The unique geometry of a zero offset VSP allows formultiples, recorded above the depth of the deepestreceiver, to be identified and removed. The end result is a zero-phase, primaries-only dataset. This datasetcan be used to identify residual multiple reflections onthe surface seismic data, as well as to phase and frequency match the surface seismic data to the zero-phase VSP.


Application: Surface Seismic AVO Calibration

Walkaway VSP, 3-D VSP


OperationBecause the VSP receiver can be placed very close to the reservoir, manyof the uncertainties associated with surface seismic AVO are eliminated.Having an in-situ receiver results in a one-way seismic travel path.Consequently, reflection amplitudes recorded in a VSP AVO survey aremuch less affected by transmission loss and scattering. In addition, witha properly designed VSP survey, wider reflection angle apertures can beacquired than with surface seismic geometry.

Benefit and ApplicationsReflection angle to offset correlationSurface-to-VSP trace amplitude calibrationSynthetic AVO response from well log dataAVO attribute analysis

Angle trace gather, two-way time sectionAmplitude variation with offset/angle cross-plotGradient vs intercept cross-plot for AVO classificationP-wave intercept trace (P), Gradient trace (G)Quick AVO synthetic from P and G and AVO synthetic stackRegression coefficients or standard deviations of curve fit on AVO cross-plotCombinations of intercepts and gradient traces,Poisson’s ratio, shear,restricted gradient, productand math-traces

AVO gradient and intercept volumes derived from surface seismicdata are used by the interpreter to provide quantitative answersregarding reservoir size, location and fluid saturation levels. Whilethey provide good spatial coverage, the seismic amplitudes recordedon the surface have traveled twice through the sediments overlayingthe reservoir. These data were affected by scattering and attenuation,and are also subject to variation due to the heterogeneity of theoverburden. There are many uncertainties inherent to surface seismicAVO. These uncertainties may manifest themselves in an erroneousreservoir model. To reduce these uncertainties, a borehole seismicAVO survey should be run to calibrate the surface seismic AVO data.

Walkaway

Synthetic AVO

Intercept AVO versus gradient crossplot

Amplitude variation with offset,AVO synthetics, an output traces presentation

Baker Atlas3-6 Geophysical Services: Borehole Seismic Applications Services Catalog Version 2.1; August 2008

Service: Zero Offset VSP, Far Offset VSP, Walkaway VSP, 3-D VSP

2-D and 3-D Imaging


Reservoir DelineationDepth prediction of seismic events ahead of and offsetfrom the drill bitTime-depth correlation with surface seismic dataStructural imagingImproves reservoir characterization by delineation offaults and pinchouts

AVO and Anistrophy Modeling and AnalysisSurface seismic AVO calibrationAnisotropy detection for accurate model buildingBetter understanding of lithology, porosity, pore fluidsand orientation of aligned fractures

2-D VSP ImagingImproved vertical and lateral resolution compared to surface seismicPhase determination and matching of surface seismicExtraction of parameters for enhanced surface seismic processingGeneration of a high-resolution velocity model at the wellboreQ compensation derived from borehole VSP dataimproves surface seismic resolution

3-D VSP ImagingSimultaneous surface and borehole seismic data acquisition reduces operating costsImproved vertical and lateral resolution compared to surface seismicUsing a shared VSP-calibrated velocity model, the 3-DVSP can be integrated with the surface seismic dataVolumetric estimates improved by high-resolution 3-D VSPTrue 3-D migration in time and depth2-D out of plane migration errors solved by 3-D migration

Salt ImagingSalt Flank Reflection ImagingSub-Salt Imaging – Map reflections beneath salt base,which are not illuminated by surface seismic3-D Salt Proximity – Refraction Methodology

Both 2-D and 3-D VSPs improve reservoir characterization. High-resolution VSP data can be integrated with surface seismic data to provide detaileddescriptions of formation properties and identification of reservoir compartments not possible with surfaceseismic data alone.

Rig source deviated borehole seismic image (VSP-CDP transform) digitally spliced into the surface seismic section.

The offset VSP provides enhanced resolution to thesurface seismic data. The offset VSP and CorridorStack are superimposed on the surface seismicdata. Data example courtesy of BP


Application: Microseismic

Hydraulic-Fracture Monitoring


Magnitude can detect microseismic events from nearby observation wells or in some circumstances, from the treat-ment well itself. Monitoring from the treatment well allowsthe measurement of trapped-mode acoustic emissions, whichdirectly measure azimuths of the open fractures. Treatmentwell detectors can also see shear-slip events away from theborehole. Ideally, a hydro-frac monitoring network wouldinclude detectors in both treatment and observation wells.

Magnitude’s expertise in microseismic monitoring uses state-of-the-art technology in seismic processing of acousticevents for quantitative results.

Leading acquisition QA and processing tools• SmartPick for semi-automated data QA• Smart monitoring for real-time processing and remote

follow-up• SeisTool for advanced signal processing and 3-D

location of eventsUnique quantitative reports• Network sensitivity maps to show detection probabilities • Location uncertainty maps to illustrate event location

statistical reliability• Event density and maximum emitted energy maps to

assist in interpretation• Seisplay (trademark of Magnitude) 4-D dynamic event

maps with tagged magnitude (energy) levels to show fracture volume development

BenefitsIndependent estimate of fracture volume and orientationLocation and orientation of pre-existing sub-seismic faultsactivated during injectionValidation of hydro-frac program parametersImproved well spacing and field development planningReduced fracturing costs through efficiency improvements Optimization of development program for minimum completion costs and maximized production

ApplicationsIndependent verification of fracture program successDynamic 4-D fracture growth characterization Estimate of rock mechanic parameters from fracture statistics

Microseismic events are detected in an observation wellthat is located away from the treatment well. The Geochain,GeoWaves and MSR tool systems are used for dataacquisition in the observation well. These micoseismicevents are used to map fractures that may occur awayfrom the treatment well. They can provide an independentestimate of fracture volume and verify fracture direction.Verification of fracture volume and direction is crucial tooptimization of a prospect development program.

Shear-slip event locations map fracture volumeand distribution

Acoustic emissions map open-fracture azimuths

Treatment well receivers record events duringpressure fall-off reduced noise conditions.Adapted from Parotidis et al. (GRL, 2004)

Acoustic Emission(A.E.) Trapped in Open Fracture

Envelope(Destabilized Zone)

Time

Injection Fall Off

Dista

nce

Microseisms Inducedby Stress Changes

Treatment Well

Observation Well

Seismic SensorSeismic

Sensor

2

Extra Coverage and Ease of Operations for Complex VSPs

GCN – Downhole Receiver Array Geochain

Downhole Instrumentation

Baker Atlas3-8 Geophysical Services: Downhole Seismic Services Services Catalog Version 2.1; August 2008

OperationBaker Atlas performs downhole seismic services in environments ranging from slim- to large-diameter boreholes, vertical to horizontal wellbores, open and cased holes, and high-pressure and high-temperature well conditions.

The Geochain system is configurable up to 42 levels. It is a high- frequency tool that is suitable for microseismic data acquisition with excellent data fidelity. Hydrophone modulescan be added to provide 4-C acquisition.

HighlightsCheckshot/VSP/Offset VSP/Walkaway/3-D VSPMicroseismicAnistropic modeling and migration2-D and 3-D imaging

BenefitsFaster acquisition of complex borehole seismic servicesvia deployment of up to 42 geophonesSuitable for high-volume 2-D and 3-D surveys and high-frequency microseismic surveys

Specifications

The 3-C GeochainSM system allows up to 42 satellites to be deployed, spaced between 1 and 75 m (3 and246 ft) apart. The array is capable of operating for longperiods in high-temperature (180° C/356° F) wells and,being a modular system, is easily expandable. The system is made up of standard tools that are adaptedto run in a multi-level configuration, making the systemhighly adaptable for different survey objectives. Whetherfor rig-time saving or for extra coverage and ease ofoperations in complex VSPs, the Geochain system isideal when those extra levels are crucial to the objective.

Downhole Receiver Array Geochain


Length 2.9 ft 0.9 m





Extra Coverage and Ease of Operations for Complex VSPs

GWV – Digital Multi-level Downhole Seismic Array


Baker Atlas 3-9Geophysical Services: Downhole Seismic ServicesServices Catalog Version 2.1; August 2008

OperationThe tool system is resistant to extreme well conditions. Each tool is lightweight in construction, comprising two sections connected by quick-coupling nuts that enable efficient rig up, rig down and maintenance.

Baker Atlas has utilized the GeoWaves tool system to successfully recordlarge 3-D VSPs for detailed reservoir imaging around the well. Otherapplications are 4-D VSPs that provide time-lapse reservoir imaging. TheGeoWaves tool system is also ideally suited to hydraulic-fracture mappingand passive seismic monitoring applications in either fixed or semi-perma-nent installations.

HighlightsLong-range, self-adapting, multi-carrier telemetryMaximum telemetry of 4 Mbit/sOver 2.5 Mbit/s on a 7,000 m standard 7-conductor wireline24-bit delta sigma convertersSample rates: 1/4, 1/2, 1, 2, and 4 msAutomatic downhole electronic testsArm opening state indicator for each levelDigital serial number identificationUp to 32 levelsOptional 3-component fixed of gimballed geophone packagesCoax inter-tool cable (fewer parts)Continuous operating temperature up to 170º C (338° F), with a peakabsolute maximum temperature of 180º C (356° F)Continuous operating pressure 22,000 psi (151.6 MPa)Light, compact and simple (fewer parts)Automatic arm closure for safe retrieval in case of power failureMade of corrosion-resistant materials (Titanium)Minimal maintenance design

FeaturesTools made of two sections connected by quick-coupling nutEasy access to geophone or electronic cartridgeEasy handling for rig up and rig downUser-friendly system softwareFast and easy removal of arm’s weak links

Specifications

The Baker Atlas GeoWavesSM tool system is a multi-level digital downhole seismic array containing up to 32 levels. The GeoWaves toolsystem has a long range, self-adapting, multi-carrier telemetry that provides superior telemetry rates for borehole seismic acquisitions.


Length 4 ft 1.23 m

Diameter - w/o pad 3.1 in. 79 mm


Temperature 338 - 356º F 170º - 180º C


Modular Downhole DigitalAuxiliary Channels

CCLTension compression meterTemperatureGamma toolWeight unit sensor

Innovative Design Allows Up to 8 Multi-Level Receivers in Slimholes

MSR – Multi-level Slimhole Receiver



OperationBaker Atlas performs downhole seismic services in environments ranging from slim- to large-diameter boreholes, vertical to horizontal wellbores, open and cased holes, and high-pressure and high-temperature well conditions.

The MSR is a unique, multi-level slimhole receiver systemwith up to eight levels. This is a high-frequency tool that is suitable for microseismic data acquisition with excellentdata fidelity.

HighlightsSlimhole production wells/PipeSeis/VSP/Offset VSP/Walkaway/3-D VSP/MicroseismicFracture analysisMonocable optionAnistropic modeling and migration2-D and 3-D imaging

BenefitsFaster acquisition of complex borehole seismic servicesvia deployment of up to eight geophonesMulti-level slimhole capability, with exceptional high-frequency response, suitable for microseismic and high-volume 2-D and 3-D surveys

Specifications

Baker Atlas can run up to eight multi-level receivers in slim production holes. An innovative design, whichdecouples the receiver from the satellite body, meansthat the MSR tool has a very high-frequency responseof over 1,000 Hz, making it ideal for microseismic orhydro-frac studies and for occasions when a VSP must be run on monocable wireline or in slimhole (<2 in.) conditions.

Multi-Level Slim Hole Receiver


Length 2.4 ft 0.7 m




Weight 20 lb 9.1 kg

Acquisition of Borehole Seismic Data Inside Drill Pipe

PSR – PipeSeis



OperationDeployment of the slimhole receiver is made through a side-entry-sub and kelly hose connected to the top of thedrillstring. When the tool is at the required measured depth,it is clamped inside the drillpipe and the seismic energy is generated by means of a conventional source at the surface.Depth is controlled by a standard wireline encoder. A numberof built-in features ensure that drillpipe does not becomestuck in the hole during surveying. The PipeSeis techniquecan be run in single- or dual-level mode using the SHR tool, or in true multi-level mode with the Multi-levelSlimhole ReceiverSM.

HighlightsVSP in drillpipeOperations in horizontal holesAcquire useful data even when drill is stuck in hole

BenefitsRig-time savingSafe alternative to pipe-conveyed loggingLook ahead of the drill in conjunction with conventional VSP to plan casing points and detect overpressure conditions

Baker Atlas offers the PipeSeis technique as an alternative to acquiring borehole seismic data usingPipe Conveyed Logging (PCL). The 3-C well seismicdata is recorded from within the drillpipe as the geophone is pumped down using the mud circulatingsystem. This technique uses conventional wireline and allows data to be recorded in wells that go pasthorizontal at a minimal risk and minimizing rig time.

Reduced Energy Absorption and Higher Penetration

Buried Gun Array



Highlights of the Baker Atlas Buried Airgun Array:Reduced energy absorbtion and higher penetrationEfficient solution for unconsolidated source environment,particularly for transition-zone and swamp VSP acquisitionEspecially suited for high-resolution VSP surveysHighly repeatable, suitable for time-lapse VSP surveysEliminates static correction changes for intermediate andfinal VSPCost-effective

Baker Atlas offers a proprietary buried airgun array.Until now, buried airgun was available only as a single-gun option with some customers preferring the increased power of the traditional array in a pit.

Buried airgun array 3x150 in3 sleeveguns 1x200 in3 buried airgun 2x200in3 buriedin a gun pit airgun array

Fully Integrated Seismic Logging System

SLS – Seismic Logging Systems

Surface Instrumentation


OperationThe SLS system has the flexibility to record digital and analog downhole receivers, surface channels, and also aninterface with 3-D surface seismic systems allowing forsimultaneous surface and downhole data acquisition.

The SLS system uses a powerful UNIXSM multitasking workstation environment to acquire, process and transmitborehole seismic data. Self-testing and monitoring of bothsurface and downhole instrumention are performed prior toand during acquisition to ensure data quality. Real-time QCdisplays allow the field engineer to monitor energy sourcefiring, raw data recording, tool depth and cable tension.

Field processing of borehole seismic data is performed usingSEISLINK software, allowing a wide range of processingcapabilities at the well site. Data transmission from locationto office or to our processing and interpretation centers ispossible using the Baker Atlas WellLinkSM service.

SLSIV Seismic on ECLIPSIntegrated borehole seismic capabilities within the openhole logging unit

Baker Atlas’ Seismic Logging System (SLS) is a fullyintegrated, efficient and reliable data acquisitionsystem for all borehole seismic applications. SLS allows for detailed quality control of all aspects of theservice including downhole data integrity, surface anddownhole instrumentation tests, source monitoring and navigation information.

Positioning Accuracy for Both Land and Marine VSP Surveys

TASMAN Integrated Borehole Seismic Navigation System



HighlightsAll types of positioning required for borehole seismic operations

Vertical incidence VSP2-D and 3-D Walkaway surveysFixed offset surveys

Purpose-built software for fast, efficient surveysComprehensive QA tools for ensuringpositioning accuracyFully interfaced to recording systems and source contollersFull control of target selection and system configuration from the rig

BenefitsReduced costsFewer personnel to transport and accomodateReduction in potential operating errors and incomplete source position informationIncreased flexibility

The TASMAN system has been developed to take advantage of recentadvances in DGPS technology andradio data telemetry. Designed from theoutset specifically for borehole seismicapplications, it provides the optimummethod for reliably and accurately positioning seismic sources with theminimum of rig time. Use of the TASMAN system means third-party navigation contractors are not required.Although the primary application is foruse in positioning marine and shallowwater sources, the system can also beused for onshore work.

DSSNAV in-survey displays

DSSNAV positioning system

SLS Interfaces with all Vibrator Electronics, Airgun and Explosives Controllers

Energy Sources and Energy Source Controllers



Energy SourcesTuned marine arraysCompressional and shear-wave vibratorsExplosivesAll other seismic sources

Baker Atlas SLS interfaces with all vibrator electronics,airgun and explosives controllers. Our airgun controllersprovide precision in VSP airgun synchronization andcontrol, and they are capable of controlling up to 16 airguns at each of eight source locations. All controllersare integrated into the acquisition system to automati-cally tune large airgun arrays and record individual gun-timing, sensor signals, near- and far-fieldhydrophones, gun pressure and depth information.

The Baker Atlas Deep Penetrating Focused array is a specialized array for deepwater and/or deep well applications.

Baker Atlas compressional vibrator unit

The Baker Atlas H-Racks are tuned, compact gunarrays that can be easily and safely deployed toproduce a high-frequency broadband signature.Both sleeve and G gun arrays are available.

2-D Imaging

Baker Atlas3-16 Geophysical Services: VSFusion Borehole Seismic Processing Services Catalog Version 2.1; August 2008

VSFusion Borehole Seismic Processing

Improve Resolution and Depth Prediction

2-D and 3-D Prestack Kirchhoff Depth MigrationsAnisotropic (TIV) 3-D depth migration2-D VSP-CDP transformFull wavefield migration3-C, 3-D migration of 2-D data

3-C VSPs Reservoir Delineation

Offset and Walkaway VSP imaging is not limited toimproving P-wave resolution. By making use of 3-Cdata, it is possible to gain a better understanding of thevarious elastic wavefields. This allows the time-depthand P-S calibration of surface seismic compressionaland shear wave studies; the study of rock properties,such as Poisson’s ratio; and an improvement in resolution by imaging the shear wave data.

Example of Velocity Model Grid – Kirchhoff Migration

Migrated VSP spliced into surface seismicVertical Incidence VSP used to improve resolution and depth prediction.

3-Component and 4-Component VSP Imaging

3-D Migration; 3-C, 3-D Migration; 4-C Processing


Baker Atlas 3-17Geophysical Services: VSFusion Borehole Seismic ProcessingServices Catalog Version 2.1; August 2008

3-C, 3-D MigrationThree-component 3-C, 3-D migrationdirectionally distributes energies totheir reflection origins, which furtherenhances the 3-D image effects. Thistechnique is especially beneficialwhen the data quantity is limited.The example shows the salt boundaryimage by three inline (2-D) sources.The lower reflector is in the off-linedirection. This result cannot beachieved by the regular 3-D migration.

4-C ProcessingWith the addition of a hydrophonemodule in the Baker Atlas acquisitiontools, full 4-C data can be processed.4-C processing allows the successfulseparation of wavefields in horizontalwells. This allows improved imagingbelow the well and derivation ofrock properties such as Vp/Vs ratios.

Method of combining geophoneand hydrophone data successfullyestablished4-C well seismic data produces ahigh-resolution image below ahorizontal well trackGuided and converted wave information can be used to confirm presence of faultsVSP imaging in horizontal wellsDiscrimination of permeable zonesImproved interpretation in complexgeological settingVp/Vs computation from P-wave amplitudes

3-D Migration

3-D migration maps the reflectionenergy in three dimensions,achieving superb delineation ofreflectors and faults thanachieved by 2-D migration. Dataexample shows a multiline 2-DWalkaway VSP migration resultsby the 2-D VSP migration (left)and by 3-D VSP migration (right).

2-D Migration 3-D Migration

4-C Borehole Seismic

Surface Seismic


Leading Technology for Processing of 3-D VSP Data

3-D VSP Processing, Interpretation and Integration


VSFusion makes use of all three recorded components forimaging each wavemode separately, taking advantage of thediffering reflectivity series of compressional and shear waves.

3-D time-depth correlationHigh-resolution seismic stratigraphyHigh-resolution structural imagingSimultaneous acquisition, 3-D surface seismic and 3-D VSPSurface seismic processing parameter calibrationVSP-derived Q compensationAVO calibration of surface seismic dataFracture orientationAnisotropy estimatesTime-lapse feasibility/baseline studies3-D InversionReservoir property analysisHigh-resolution attribute mappingFull 3-D visualization

VSFusion provides the leading technology for the processing and interpretation of 3-D VSP data. The true value of a 3-D VSP dataset is extracted throughintegration with CGG’s surface seismic reservoir characterization and comprehensive rock propertyanalysis in conjunction with Baker Atlas GeoscienceCenters. This approach reveals lateral facies variations,high-resolution sequence stratigraphic information andattribute maps linked to petrophysical information suchas porosity, as well as the traditional high-resolutionstructural imaging and time-depth correlation.

3-D Surface Seismic

3-D Surface Seismic

3-D VSP Splice

Baker Atlas 3-19Geophysical Services: VSFusion Borehole Seismic Processing

Estimate the Decay of High Frequencies with Depth

Q-Compensating Surface Seismic Data



Attenuation in seismic data is governed by energy loss per oscillationover a given travel time. High frequencies exhibit higher level of oscillation and are more prone to attenuation.

Using the VSP downgoing wavefield recorded at successive depths inthe borehole, it is possible to estimate the decay of high frequencieswith depth. The frequency decay estimate can then be inverselyapplied to surface seismic data to restore lost bandwidth.

Original processing

VSP-derived Q-compensated processing

Reprocessing VSPs and Rock Properties from VSP Data

Special Processing



Rock Properties from VSP DataBy utilizing information from all three components in the VSP tool, amplitude-consistent processing may be performed for reservoir characterization and rock propertyanalysis. Surface seismic processing benefits greatly frominformation gathered from 2-D or 3-D borehole seismic data.

Amplitude-consistent 3-C processingAVO estimates for surface seismic calibrationFracture orientation from azimuthal amplitude variationsAnisotropy estimates through slowness curve inversionTau-P domain walkaway VSP processingP- and S-wave estimates and ratiosPoisson’s Ratio, elastic propertiesFracture detectionGlobal/effective overburden anisotropy calculations2-D and 3-D elastic inversion for high-resolution stratigraphic analysisEstimates of Q at the borehole to compensate for Q insurface seismic data

Special Products and ProcessingInversion for attributesOver-pressure indicatorWavelet matching and extraction

Reprocessing VSPs

If you have suboptimal images from archived VSP data,then reprocessing could be the answer. Advances inVSP processing from VSFusion can yield high-qualityseismic images without having to reshoot the survey.

Customize your displays and improve your imaging to reveal hidden information in old datasets, such asfracture networks and lateral stratigraphic changes.Reprocessed VSPs can be fully integrated with new orreprocessed surface seismic data. Reprocessing offerscost-effective advantages for all types of VSP data fromstandard checkshots to walkaway, 3-D and AVO analysis.Old data archived on paper can be reprocessed andstored in digital format for reliable preservation.

VSP – 3-Component Rotation

(Left) Direct Component contains downgoing Pand reflected S energy

(Right) Perpendicular Component contains down-going shear wave and reflected P-wave energy

Update Presurvey Modeling to Best Match VSP Seismic Data

Post-Survey Modeling



SituationA deviated well to run sub-horizontally within a reservoirPoorly defined surface seismic data with 100 m lateraland 50 m vertical errorsA requirement to penetrate the fault at a certain locationwithin the reservoir

ObjectivesRun intermediate Vertical Seismic Profile (VSP), thenperform on-site processing within six hoursMatch real results to synthetic modeling, and adjust model

Solution/BenefitsProvided high-resolution seismic information duringdrilling of the wellCustomer able to quickly adjust well trajectory and enter target zone at desired point of entry with lower risk of uncertainty

Presurvey modeling is used to optimize survey geometryto meet a given objective before the data is acquired. In post-survey modeling, the starting model is updatediteratively by comparing the final processed arrival timesand VSP data with the model. As the model is updatedto best match what is being observed in the VSP seismicdata, important structural and rock property informationis revealed, such as accurate positioning of faults, saltboundaries and formation velocities.

3-D Layer-Based Inversion Improves Vertical Resolution

2-D and 3-D VSP Inversion



The available outputs consist of the input data, and variousmodel parameter images presented as time images, spikeimages, and the derived images of impedance, velocity anddensity. For quality control, the solution can band-limited tomatch filtering applied to the input surface seismic data.

3-D VSP InversionVSFusion performs 3-D VSP using the TDROV 3-D technique, the only 3-D layer-based inversion service available on the market. It features a new multi-volumecapability for 4-D, 4-C and AVO processing. The TDROVtechnique derives a finely layered impedance model, givingaccess to the architecture of the reservoir. Elastic impedanceis estimated from the 3-D seismic (surface or boreholederived), using well data as calibration for the wavelet and for obtaining the low-frequency component of elasticimpedance. TDROV technique follows a model-basedapproach where the model parameters are sparse and constrained. The key advantage of the layering approach is improved vertical resolution. In addition, the layeredimpedance model allows a quick QC of the inversion, mapping of impedances along the stratigraphy, and an easy description of reservoir properties.

Prediction of Events and Pressures Ahead of the Bit

While prediction ahead of the bit is not a new technique,advances through VSFusion’s inversion method and processing software are achieving improved accuracy. TheVSP trace at the borehole is inverted to generate an acousticimpedance log below TD. Acoustic impedance changes onthe log can provide indications of rock type and propertiessuch as reservoir sands and over pressured zones. VSPimaging can also be used for visualizing formations in frontof the bit.

2-D VSP Inversion

VSFusion’s Sparse Spike Inversion application estimates the impedance profile, velocity, den-sity and depths. Sparse spike inversion mixesa seismic wave field with the low frequencycomponents of a reflectance series generatedfrom an input model. The input model can bedeveloped from VSP first break time-depth ofreceiver pairs, TD-pairs or from a VSP check-shot survey. Models developed using thisapplication initially consist of horizontal planelayers. Dipping and nonplanar layers are thenadded through the interactive editor.

Velocity model

Position VSP Receivers to Achieve Desired Results

Presurvey Modeling



In conjunction with GeoTomo LLC, VSFusion uses theVECON™ modeling package, which quickly and easilymodels VSP surveys even with the most complex of subsurface structures. This ease of use and flexibility provides answers to VSP survey design questions before thesurvey is acquired. With the VECON package loaded on alaptop PC, a VSFusion geophysicist is able to model anytype of survey with the customer. Geologists, geophysicists,drillers and other interested staff in the customer’s office areable to participate in the survey design and add valuableinsight to the process. The VECON package allows the geophysicist to:

Design and Model All Types of VSP SurveysInteractively design the survey on UNIX® workstation or Windows® PCPredict the full-wavefield responsePerform advanced ray-tracing and finite-difference modelingSimulate P- and S-wave source as well as P-S and S-Pmode converted wavefieldsInput starting model from any image file or SEGY and digitize on-the-flyVisualize models in 3-D

Borehole seismic surveys need to be optimized if theyare to meet survey objectives and remain within budget.Presurvey modeling aids in positioning the VSP receiversat the proper depth and the sources at the correct off-set and azimuth to achieve the desired results.

Cased Hole Formation EvaluationProduction LoggingPipe Evaluation

4. Reservoir and Production Services

IV

Baker Atlas4-2 Reservoir and Production Services: Cased Hole Formation Evaluation

Cased Hole Formation Evaluation

To find zones of opportunity in cased wells, it is necessary to run logs that can identify hydrocarbons behindcasing. Pulsed neutron services such as Baker Atlas’ Reservoir Performance MonitorSM (RPMSM) and PDK-100SM

instruments differentiate between water- and hydrocarbon-bearing formations to identify bypassed or partiallydrained areas of the reservoir. Pulsed neutron analysis can also estimate formation properties (porosity, shalevolume) and hydrocarbon type necessary to develop an optimal perforating and completion program. The datacan be used to optimize hydrocarbon recovery for a single well or an entire field.

By periodically monitoring reservoir fluid saturations and gas/oil/water contact levels, reservoir models can be continually refined, impacting decisions ranging from daily wellsite operations to initiating secondary or tertiary recovery. In addition, the use of these services can also help avoid premature well or field abandonmentby identifying bypassed hydrocarbons that could be recovered economically from the reservoir.

More in-depth information for each service is available online on the Baker Atlas website. Please contact yourlocal customer service representative, or log on to www.bakeratlasdirect.com for more information and a complete list of Baker Atlas services.


Technology

Reservoir Performance MonitorPDK-100

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RPM – Reservoir Performance Monitor

Baker Atlas 4-3Reservoir and Production Services: Cased Hole Formation Evaluation

C/O and PNC Sw, Gas Saturation, 3-Phase Water Holdup and Water Flow Measurements


Advanced Comprehensive Pulsed Neutron Instrument

The RPM addresses a broad scope of reservoir evaluation and management applications, including reservoir saturation and produced fluids monitoring, formation evaluation, production profiling, workover and well abandonment evaluation, and identification of water channeling for mechanical integrity testing.

Operation

The RPM service instrument employs three high-resolution gamma-ray detectors anda new, more efficient and reliable neutron generator. State-of-the-art detector elec-tronics measure both the arrival time and energy of detected gamma rays. Theneutron generator is pulsed at distinct frequencies and the detectors operate in variousacquisition modes to obtain the different logging measurements. This allows multipleoperating modes during a single trip in the well resulting in more efficient wellsiteoperations. The RPM can also be run in memory mode for PNC-Sigma logging.

HighlightsIdentification of hydrocarbons behind casing Measurement of fluid saturations in fresh, mixed salinity water environments (C/O)Measurement of fluid saturations in saline water environments (PNC-Sigma)New quantitative gas saturation measurement (GasView)Multiphase holdup measurements in production profilingMeasurement of water velocity in production profilingIdentification of water channeling, casing leaks, flow behind pipe

BenefitsValuable tool for formation and reservoir evaluation, monitoring, and managementIdentify and assess commercial value of bypassed hydrocarbons prior to wellabandonment and evaluation of workover effectivenessRPM data can be matched with previous generation PDK-100SM data for monitoring programs in mature fieldsApplications in Mechanical Integrity Testing (MIT) Memory mode capability for PNC-Sigma logging

Specifications – 8281 Series RPM-C

The Reservoir Performance Monitor (RPM) is an advanced slimhole multi-function pulsed neutron tool with industry-leading accuracy and precision, combining multiple nuclear measurements in one system. Carbon/Oxygen(C/O) and pulsed neutron capture (PNC or Sigma) operating modes providemeasurements for water saturation. In addition, a new quantitative gas saturation measurement service called GasViewSM is available that is uniquein the industry. The RPM also has applications in production logging. ThePulsed Neutron Holdup Imaging (PNHI) mode provides three-phase holdupdetermination, and several oxygen activation modes (Hydrolog, FloShot andAnnular Flow Log) provide quantitative water velocity measurements under avariety of completion configurations.

RPM-PNC Primary log display. While RPM-PNC data acquisition and processing provide superior analysis, resultsand statistics, the log display is similar to the conventional PDK-100 presentation.

Hydrocarbon depletion monitoring of a sandstonereservoir using RPM-C/O analysis.






Weight 75 lb 34 kg*Contact your Baker Atlas

representative for other series.


Proven Pulsed Neutron Capture Technology Helps to Assess Hydrocarbon Reserves

PDK – PDK-100

Enhanced Formation Evaluation and Reservoir Monitoring

Reservoir and Production Services: Cased Hole Formation Evaluation

Operation

The PDK-100 instrument measures the macroscopicthermal neutron absorption cross-section (sigma) of thebulk formation. Sigma is primarily a function of porosity,formation water salinity, quantity and type of hydrocarbonin the pore spaces, and type of rock matrix. Sigmadecreases with increasing hydrocarbon content, butincreases with increasing water salinity. In cased holes,the PDK-100 instrument can be used to discriminatebetween gas, oil and saltwater-bearing formations.

HighlightsIdentification and saturation of hydrocarbons incased holes Reservoir monitoring of formation gas/oil/water contactsAccurate sigma measurements in flowing or static conditions

BenefitsValuable tool for formation and reservoir evaluation,monitoring and managementIdentify and assess commercial value of bypassedhydrocarbons prior to well abandonment and evaluation of workover effectiveness


The PDK-100SM (Pulse and Decay 100 channels)instrument employs pulsed neutron capture (PNC)technology to provide high-resolution measurementsof thermal neutron decay to help evaluate hydrocarbonreserves in formations containing saline water. ThePDK-100 has long been a standard for PNC loggingin reservoir monitoring applications.







*Contact your Baker Atlas representative for other series.

The PDK-100 instrument provides valuable information for developing accurate 3-D reservoir depletion models.

Primary log presentation

Production Logging Services are necessary for a full evaluation of the static and dynamic conditions of thereservoir. Real-time, depth-correlated production data including flow rates, pressures and gas/oil/water ratiosprovide input for pressure transient and nodal well test analysis and reservoir simulation. Using these key pro-duction parameters, it is possible to evaluate drilling and production operations at the wellsite and diagnosepotential problems such as water or gas breakthrough, crossflow of thief zones and channeling.

More in-depth information for each service is available on the Baker Atlas website or in the Baker AtlasPOLARIS brochure. Please contact your local customer service representative, or log on towww.bakeratlasdirect.com for more information and a complete list of Baker Atlas services.


Baker Atlas 4-5Reservoir and Production Services: Production Logging

Production Logging


POLARIS – Production Optimization Log and Reservoir Information Solutions

Baker Atlas4-6 Reservoir and Production Services: Production Logging

Multifunction Reservoir Evaluation and Well Performance Monitoring

Advanced Production Logging For Highly-Deviated and Horizontal Wells


Operation

The MCFM instrument is the premier multiphase production loggingtool developed for non-vertical wells. The small diameter multisensorMCFM instrument incorporates sophisticated technology for measuringthree-phase flow – oil, water and gas – in horizontal, highly deviated andundulating wellbores. Combining an across-the-wellbore capacitancearray with temperature, pressure and acoustic sensors allows the MCFMinstrument to pinpoint the location of three-phase entry into the wellbore.In addition, flow velocities are measured at six levels across the wellboreby cross-correlation of signals measured along each row of sensors.Correlation velocities are supplemented with spinner velocity for a totalof up to seven velocity measurements across the wellbore.

The RPM is an advanced multifunction pulse neutron tool which combinesmultiple nuclear measurements in one system with industry-leadingaccuracy and precision. Carbon/Oxygen and pulse neutron capture measurements acquired with the RPM tool provide water saturation andthree-phase holdup determination while oxygen activation measurementsdetect and quantify water flow and channeling.

HighlightsComplete package of advanced and conventional PLT measurementsAcross-the-wellbore multiphase and velocity distribution profilesMultiphase flow rates in highly-deviated and horizontal wellboresOxygen activation for independent measurements of water velocityand channel detectionPulsed neutron water saturation measurementsAuxiliary acoustic and temperature measurements for fluid entry,channeling and leak detectionDeployment on coiled tubing, tractor or wireline

Benefits Provides high-resolution data for reservoir evaluation, monitoring and managementIdentify and assess commercial value of bypassed hydrocarbons priorto well abandonmentAllows intelligent planning of well-performance enhancement

Specifications

The Baker Atlas POLARISSM System is an exclusive combination of the Multi-Capacitance Flow MeterSM (MCFMSM) and ReservoirPerformance MonitorSM (RPMSM) logging tools – creating a powerfulslimhole diagnostic system for evaluating and understanding performance in highly-deviated and horizontal well and reservoirs.

The wings of the MCFM tool are maintained in the vertical position tomeasure multiphase flow behavior in horizontal wells.

MCFM sensors are deployed acrossthe wellbore to determine phase fraction (holdup) and velocity profiles.Holdup and velocity data is acquiredsimultaneously within the 30-inch longwing assembly and sensor package.


Length 80 ft 24.4 m





Determine Flow Rate of Multiphase Flow in Vertical or Deviated Wells

PRAL – Production Logging Services

Efficient Production Logging Services

Baker Atlas 4-7Reservoir and Production Services: Production LoggingServices Catalog Version 2.1; August 2008

Operation

A variety of sensors provides accurate, high-resolution logseven under difficult well conditions including multiphaseflow, various flow regimes, and low-to-high flow rates.

Sensors available include casing collar and gamma ray correlation, temperature, pressure, gradiomanometer andinline and fullbore flowmeters.

HighlightsEvaluate reservoir performance including downholeflowrate and profile and reservoir component(s) contributionDiagnose production or injection problems such asunusual changes in production, channeling, leaks, cementor stimulation failures, crossflow or thief zones, and gasor water coning

BenefitsEfficient wellsite evaluation of production and injectionprofilesDeployment in limited space rig ups

Specifications

Production Logging Services provide a full evaluation of the static and dynamic conditions of the reservoir.Real-time, depth-correlated production data includingflow rates, pressures and gas/oil/water ratios provideinput for pressure transient and nodal well test analysisand reservoir simulation. Using these key productionparameters, it is possible to evaluate drilling and production operations at the wellsite and diagnosepotential problems such as water or gas breakthrough,crossflow of thief zones and channeling.






Weight lb kg


Meter Fluid Flow Rates in Either Cased Hole or Openhole Wells

FMCS – Continuous Spinner Flowmeter

Determine Velocity and Direction of Fluid Movement

Baker Atlas4-8 Reservoir and Production Services: Production Logging Services Catalog Version 2.1; August 2008

Operation

Continuous Spinner Flowmeter surveys can be used formetering fluid flow rates within cased hole or openholewells. The velocity and direction of fluid movement inthe borehole can be determined by the ContinuousSpinner Flowmeter.

Units of measurement are revolutions per second, whichcan be converted to barrels per day and percentage offull flow. The latter is usually presented in a flow profilederived from a log made with a stationary instrumentor an instrument moving at constant speed.

HighlightsInjection and production profiles to indicate relativefluid movement from or into a zone of activity Locate points of increased production due to well treatmentDetect the loss of production due to crossflow or thief zonesDetect packer and plug leaksDetect zones of lost circulation in openholes

BenefitsPrevent further production lossesRepair tubing or packer failuresIdentify zones requiring stimulation to improve production


Production Logging Services provide a full evaluation of the static and dynamic conditions of the reservoir. Real-time, depth-correlated production data including flow rates, pressures and gas/oil/water ratios provide input for pressuretransient and nodal well test analysis and reservoirsimulation. Using these key production parameters,it is possible to evaluate drilling and productionoperations at the wellsite and diagnose potentialproblems such as water or gas breakthrough,crossflow of thief zones and channeling.






Weight 5.0 lb 2.3 kg


Correct Flowmeter Readings for Diameter Variations

FMFI – Folding Impeller Flowmeter

Determine Caliper Variations During Continuous Flowmeter Run


OperationFolding Impeller Flowmeter surveys can be used for meteringfluid flow rates within cased hole or openhole wellbores.Velocity and direction of fluid movement in the borehole canalso be determined. Units of measurement for this service arerevolutions per second, which can be converted to barrels perday and percentage of full flow. This percentage is usuallypresented in a flow profile, derived from either a stationaryinstrument or an instrument moving at a constant speed.

The caliper version of this instrument can be used to determinediameter variations during a continuous logging run. These dataare used to correct the flowmeter readings for diameter variationsdue to heavily scaled tubular goods or to differences in open-hole completions. The caliper measurement point correspondsexactly to the measurement point of the flowmeter impeller.The caliper data can be used independently for determininginternal corrosion, paraffin buildup or mineral scaling.

HighlightsProvide injection and production profiles to indicate relativefluid movement from or into a zone of activity Locate points of increased production due to well treatmentDetect loss of production due to crossflow or thief zonesDetect packer and plug leaks Detect zones of lost circulation in openholes

BenefitsPrevent further production losses Repair tubing or packer failuresIdentify zones requiring stimulation to improve production


Production Logging Services provide a full evaluation ofthe static and dynamic conditions of the reservoir. Real-time, depth-correlated production data including flowrates, pressures and gas/oil/water ratios provide input forpressure transient and nodal well test analysis and reser-voir simulation. Using these key production parameters, itis possible to evaluate drilling and production operationsat the wellsite and diagnose potential problems such aswater or gas breakthrough, crossflow of thief zones and channeling.








Determine Flow Rate of Multiphase Flow in Vertical or Deviated Wells

FMBK – Basket Flowmeter

Measurement of Low Flow Rates


OperationThe Basket Flowmeter is used for metering low flow rateswithin cased hole or openhole wells. The motor-drivenBasket Flowmeter is lowered in a closed position into thewell through tubing. It is then opened to take stationaryreadings at the point of interest. Once opened, the flow isdirected through the center of the instrument, where rotationalvelocity of the spinner is proportional to the velocity of thefluid movement.

Two-phase flow rates can be measured accurately, particularlywhere fluid velocities are low. In high-angle wells, log interpre-tation are enhanced where water hold-up and fluid separationare occurring due to the improved mixing of phases causedby diversion of flow through the spinner chamber.

HighlightsProduction profiles to indicate relative fluid movementfrom the zones of activity Injection profiles to determine intervals acceptinginjected fluid Detect the loss of production due to crossflow or thief zonesDetect packer and plug leaksDetermine flow rate of multiphase flow in vertical or deviated wellbores

BenefitsProduction profiles to indicate relative fluid movement fromthe zones of activity-best choice in low flow rate conditionsDetermine flow rate of multiphase flow in vertical or deviated wellbores


Production Logging Services provide a full evaluation ofthe static and dynamic conditions of the reservoir. Real-time, depth-correlated production data including flowrates, pressures and gas/oil/water ratios provide inputfor pressure transient and nodal well test analysis andreservoir simulation. Using these key production param-eters, it is possible to evaluate drilling and productionoperations at the wellsite and diagnose potential problemssuch as water or gas breakthrough, crossflow of thiefzones and channeling.








Density Differences Between Water, Oil and Gas Identify Fluid Type

FDN – Nuclear Fluid Density

Locate Entry of Fluids/Determine Phase Fractions


OperationThe Nuclear Fluid Density log is a radioactive measurementwhich uses gamma rays. While the Gamma Ray log is a measurement of natural gamma rays, the Nuclear FluidDensity log data are a record of the density differencebetween water, oil and gas, and are generated by use of achemical gamma ray source. The density measurement ismade by observing the relative absorption of gamma rays bythe borehole fluid in a sampling channel. The basic unit ofmeasure is a count of residual gamma rays. This countingrate is inversely proportional to the density of the sample andis a function of the activity of the gamma ray source. The logdensity data are recorded in grams per cubic centimeter.

The Nuclear Fluid Density instrument, unaffected by fluidviscosity or fluid velocity, is a good indicator of the type offluid entering, leaving or present in the borehole.

HighlightsLocate entry of primary and secondary fluids in a 2- or 3-phase production flow Provide a density profile in a multiphase production flow Determine flow regime Locate borehole levels in static and flowing conditions Locate product levels in storage wells

BenefitsLocate entry of primary and secondary fluids in a 2- or 3-phase production flow to address well intervention plansGenerate a fluid density profile in a multiphase productionflow for production engineering decisions


Production Logging Services provide a full evaluation ofthe static and dynamic conditions of the reservoir. Real-time, depth-correlated production data, including flowrates, pressures and gas/oil/water ratios provide inputfor pressure transient and nodal well test analysis andreservoir simulation. Using these key production param-eters, it is possible to evaluate drilling and productionoperations at the wellsite and diagnose potential problemssuch as water or gas breakthrough, crossflow of thiefzones and channeling.








Identify Well Fluids in Multiphase Flows

WHI – Water Holdup Indicator

Quantitative Evaluation of Water Fraction Occupying Borehole


HighlightsLocate water entry into hydrocarbon flow Locate hydrocarbon/water interface in shut-in well conditions Locate hydrocarbon entry into water Identify well fluids in multiphase flows; use withFluid Density log in three phases Locate top of water column in a production well

BenefitsLocate water entry into hydrocarbon flow – identifyand correct production problems for optimized flowIdentify well fluids in multiphase flows; use withFluid Density log in three phases – locate source of water


The Water Holdup Indicator log provides a quantitative evaluation of the percent of wateroccupying the borehole (water holdup). When oildensities approach the density of water, the WaterHoldup Indicator log can yield far more definitionthan conventional fluid density measurements.When three phases are present in a flow regime,both the Fluid Density log and the Water HoldupIndicator log are required for a quantitative analysis.






Weight 16 lb 7.3 kg


Measure Low Flow Rates, Locate Channeling, Thief Zones and Tubing/Casing Leaks

Nuclear Flolog (NFL) and Tracerlog (TRL)

Fluid Movement in Low Rate Production or Injection Wells


Nuclear Flolog

The system utilizes two gamma ray detectors with aknown separation distance between them. For thistype of system, the time of ejection is not criticalbecause the information obtained is a function of thetime required for the radioactive tracer material totravel from one detector to the other detector (“time-of-flight”). The travel time is a function of the flowrate into or out of the formation at the level of measurement. The time intervals are measured to thenearest 0.1 second and tabulated for calculation. Byvarying the distance between the detectors, low tohigh flow rates can be accurately determined.

Highlights/BenefitsQuantitative analysis of injection or production profiles in low flow ratesLocation of thief zonesLocation of tubing and casing leaks

Specifications – Series 8219 Nuclear Flolog

The Nuclear Flolog is very useful in low flow rateproducing or injection wells where relatively lowflow velocities are recorded. It is typically used tomeasure flow velocities inside the casing or tubing string.








Tracerlog

Tracerlogs use a single gamma ray detector torecord the movement of radioactive tracer materialinjected into a borehole fluid to allow tracking thefluid as it moves through perforations into permeablestrata. The data can also be used to detect channelingby monitoring the migration of radioactively–taggedfluid through channels behind pipe using multiplepass time-lapse logging.

Highlights/BenefitsLocation of channeling behind pipe and thief zonesLocation of fractures and evaluation of effectivenessof frac jobsLocation of annulus cement tagged with radioactive materialLocation of tubing and casing leaks

Specifications – Series 2149 TracerLog


Length 17.92 ft 5.462 m






PNHI – Pulsed Neutron Holdup Imager

Baker Atlas4-14 Reservoir and Production Services: Production Logging

Pulsed Neutron Imaging For Three-Phase Holdup in Casing and Annulus

Advanced Pulsed Neutron Production Logging Applications


Operation

The RPM instrument employs a high-energy pulsed-neutronsource and three high-resolution gamma ray detectors in various modes of operation for formation evaluation, watervelocity and 3-phase holdup measurements. The PNHI measurement for 3-phase holdup is based on neutron-gammaray interactions that are sensitive to changes in the phases present in the wellbore. Specifically, the Carbon/Oxygen (C/O)ratio is used to determine the fraction of water relative tohydrocarbon, and a ratio of inelastic gamma rays between twodetectors is used to determine the fraction of gas to liquidphases. By combining the two measurements, a 3-phase solution for phase fraction (holdup) is determined.

Highlights Measurement of 3-phase (water, oil, gas) holdups in horizontal and highly deviated wellsDetermination of 3-phase holdups in annular flow behindtubing, slotted liners, gravel packs (when logged in combination with MCFM instrument)Detection of water, oil, or gas channeling behind pipeDetermination of fluid types above or below packers in tubing completions

BenefitsEssential measurement for production evaluation in complex completions


The Pulsed Neutron Holdup Imager (PNHI) is a mode ofoperation of the Reservoir Performance Monitor (RPM)used for determining the wellbore fractions of water, oil andgas (holdups) in horizontal and highly deviated wellbores.Because neutrons have the ability to penetrate the tubing,liner or casing, it is also an essential measurement whenused in combination with the MCFM instrument in POLARISoperations for evaluation of complex completions whereannular flow may exist. Typical annular flow conditions includeflow in a tubing-casing annulus, behind slotted liners or ingravel packs. The measurement is also useful for locatingwater or gas channeling behind casing.






Weight 75 lb 34 kg


HYDL – Hydrolog

Baker Atlas 4-15Reservoir and Production Services: Production Logging

Waterflow Measurement and Diagnostics in a Variety of Well Completions

Accurate Detection of Waterflow


Operation

The Hydrolog service uses oxygen activation for accuratedetection and quantification of waterflow. A high-energy (14 MeV) pulsed neutron source activates oxygen nuclei, creating nitrogen-16, a rapidly dissipating radioactive isotope.Background measurements by multiple detectors allow forwaterflow detection and velocity determination. The source anddetector arrangements can be reversed, depending on waterflowdirection. Different modes of operation, including specific neutron source utilization and logging procedures, are availabledepending on the complexity of the completion and/or watervelocity range. For example, the Annular Flow Log service isused to measure injection profiles in multiple string completionswhere as many as three concurrent and co-directional waterflowstreams are present. The FloShot mode is a multi-detectormethod that allows measurement of water velocities in excessof 500 ft/min (152.4 m). In addition, all oxygen activation serv-ices can be run as continuous or stationary logging measure-ments.

Highlights Multiple modes of operationIdentification of waterflow behind casingProduction and injection water profiling Continuous logging capability for complete zone coverageStationary measurements for improved precision whenrequiredDetect flow in either liquid-filled or air-filled wellboresProvide accurate waterflow diagnostics in a single logging run through multiple string configurations with multiplewaterflow pathsDetect waterflow in either up or down directions


The HydrologSM service can be used in production loggingapplications including production and injection profiling,and in problem detection such as channel identification oras a stand-alone service accepted for mechanical integritytesting (MIT) programs. The Hydrolog service offers severaladvantages over conventional services, including reducingcostly down time during production or injection operationsand eliminating radioactive tracer contamination.






Weight 75 lb 34 kg


Benefits Valuable tool for production andinjection evaluationEvaluation of effectiveness ofworkover programsMulti-mode operation allows efficient wellsite and single-trip operationsEliminate radioactive tracer contamination risk at wellsite

Locate Gas-Liquid Interfaces

SRPG – Surface Readout Pressure Gauge

Record Minute Pressure and Temperature Variations


OperationVarious gauge types with different resolutions for specific applications are offered by Baker Atlas. Theyare normally run in combination with other productionlogging services. Contact your Baker Atlas representativeto determine the proper gauge and tool combinationfor your application.

HighlightsMeasure shut-in and flowing pressure at prescribed depth levels Determine pressure differentials over prescribed intervalsAccurately locate gas-liquid interfaces (2-phase, 3-phase contacts) Estimate damage or improvement by skin factor value Measure pressure buildup

BenefitsMeasure shut-in and flowing pressure at prescribeddepth levels for optimum production designMeasure pressure buildup for reservoir management

With Baker Atlas Logging Services’ Surface ReadoutPressure Gauges, minute pressure changes andtemperature variations in a well can be detectedand recorded. Temperature is simultaneously meas-ured for readout and for compensation of sensorresponse. Any pressure changes observed arerecorded on the surface as they occur. Plots thatare available at the wellsite include flowing pressure gradient survey, static pressure gradientsurvey, flowing pressure survey, log-log buildup andHorner buildup.

Records Distinctive Sounds made by Flowing Liquids or Gas

SON – Noise (Sonan) Log

Determine Fluid Flows Inside or Outside Casing


OperationA series of band-pass filters separates the frequency spectrumof the sound for analysis of the individual amplitudes contained in each band. From model studies in the laboratoryand experience in the field, the relative energy levels in thefour bands of frequencies can be related to single- and dual-phase flow and the probable location of the flow.

Often considered to be a production logging instrument, theSonan Log can also be definitive in openhole while drillingand during completion. To aid interpretation, the Sonan Logoften is recorded in combination with a Temperature Log.

HighlightsDetermine fluid flow behind or inside casing Locate fluid flow in cement annulus channel Locate gas or liquid entry through casing leaks Locate gas/liquid interface in wellbore Determine whether fluid flow is single or dual phase

BenefitsLocate underground blowouts and lost circulation zonesfor remediation or well controlIdentify gas entry points for production planning Determine fluid flow behind or inside casing for remediation or production planning


Liquid, gas, or a combination (single and dual-phase)have a distinctive sound when flowing through restric-tions such as channels behind casing, perforations orcasing leaks. This sound is detected and recorded onthe Sonan Log.






Weight 11 lb 5 kg


The Temperature/Sonan (Noise) Log combination can be used to locate fluid entry into the wellbore,underground blowouts, and lost circulation zones.

3000

3100

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3300

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3500

3600

3700

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4500

135 140 145 150 155

TemperatureProfile

Band Pass,Line Corrected

Raw Data,Line Corrected

200-600 Hz600-1000 Hz1000-2000 Hz>2000 Hz

Calculate Continuous Differential Temperature Curve at Surface

TEMP – Temperature Log

Continuous Temperature Measurement of Borehole Fluid


OperationA stable precision probe measures precisely the temperature of the particular borehole environment. The temperature is presented on the log in units ofdegree per chart division. Continuous temperature logs are readily made in liquids; however, stationarymeasurements may be required in a gas.

HighlightsLocate points of gas entry in open and cased holesDistinguish producing zones from non-producing zonesDetermine the geothermal gradient Determine injection points and under some conditions develop an injection profile Locate tubing and casing leaks, particularly when the leaking fluid is gasTime-lapse shut-in or flowing temperature surveys toevaluate injection and production intervals

BenefitsLocate points of gas entry in open and cased holes Determine the geothermal gradient

Specifications – 8255 Series*Temperature/Pressure Combination Instrument

The Temperature Log provides a continuousmeasurement of borehole fluid temperature. From the absolute borehole fluid temperature, acontinuous differential temperature curve can becalculated at the surface. The differential data isobtained by comparing a particular absolute tem-perature value with one obtained at a precedingtime. Because the differential curve is more sensi-tive to small temperature changes, it has proven tobe useful in log interpretation applications.






Weight 13.2 lb 6 kg


Pipe Evaluation

Baker Atlas 4-19Reservoir and Production Services: Pipe EvaluationServices Catalog Version 2.1; August 2008

Pipe string failure due to corrosion or mechanical defects can occur at anytime in the life of a well. To protect yourinvestment, regular inspection of the production tubing and casing using Baker Atlas’ pipe evaluation servicescan provide early detection of problem areas and allow for timely planning of remedial action.

More in-depth information for each service is available on the Baker Atlas website. Please contact your localcustomer service representative, or log on to www.bakeratlasdirect.com for more information and a completelist of Baker Atlas services.


Technology

Vertilog ServiceDigital Magnelog ServiceCalipers Imaging Caliper Circumferential Borehole Imaging*

* For details on this service see Section 1, page 1-27

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XX

XX

XX

X

XX

XX

X XX

X

XX

OperationDefects with diameters as small as 3/8 in. (9.5 mm) canbe identified, and pipe sizes from 27/8 in. to 133/8 in. (73 mm to 339.7 mm) can be evaluated with standardequipment. Casing sizes from 133/8 to 22 in. (339.7 to558.8 mm) can be evaluated upon request.

In some sizes, the same high-quality corrosion inspection log can be produced using conventional single-conductor electric wireline or slickline (down-hole digital memory) data acquisition.

HighlightsPerform rapid 360° tubing inspectionDetect corrosion and depth of penetration; a baselog and periodic surveys can help monitor corrosion Differentiate between metal loss and metal gain aswell as internal and external corrosion defects Determine the effectiveness of cathodic protectionand corrosion inhibitorsIdentify and evaluate defects due to mechanical failure – distinguish between general corrosion, isolated pitting, and perforations or holes in the pipeEstablish the need for liner or remedial cement jobs

BenefitsEvaluate remaining strength of casing and tubing toensure continuous production360° identification of casing defects to avoid production downtimeIdentification of defects as external or internal

Specifications – 4915 Series* for 5.5” (139.7 mm) casing

The VertilogSM Service uses magnetic flux-leakage measurements to identify and quantify the extentand penetration depth of both internal and externalcorrosion defects. The overlapping arrays of fluxleakage (FL) sensors and discriminator (DIS) sensors provides full circumferential inspection ofthe tubing or casing string, allows for differentiatingbetween metal loss (corrosion) and metal gain(hardware) features, and distinguishes betweengeneral corrosion and isolated pitting.






Weight 350 lb 159.1

*Contact your Baker Atlas representative for other sizes.

Standard Vertilog presentation

Typical flux leakage (FL) and discriminator (DIS) sensorresponse to common defects – The FL sensors respond tointernal and external anomalies, while the DIS sensorsrespond to internal anomalies only.

FL

External

Internal Hole

DIS

Fully Circumferential Inspection of Tubing or Casing String

VRT – Vertilog Service

Identify and Quantify Internal and External Corrosion Defects

Baker Atlas4-20 Reservoir and Production Services: Pipe Evaluation Services Catalog Version 2.1; August 2008

Detect Wall Thickness Changes in Single or Multiple Casing Strings

DMAG – Digital Magnelog Service

Multifrequency, Multispacing Casing Inspection

Baker Atlas 4-21Reservoir and Production Services: Pipe EvaluationServices Catalog Version 2.1; August 2008

OperationThe casing wall thickness is determined by the amountof magnetic field shift, which is affected by casingthickness and permeability. An electronic calipermeasures the magnetic permeability of the voidbetween the tool and the inner wall of the casing, indicating average inside diameter. A differentialanomaly indicator provides a curve which displayssmall defects on the inside wall of the casing.

The wall thickness and caliper measurements permit adistinction between internal and external loss of metalfrom the casing. External loss is shown on the wallthickness curve. The electronic caliber and anomalyindicator detector curves respond to metal loss fromthe inside of the casing.

All data – phase shift, amplitude, circumferential section calipers and differential anomaly indicator –are recorded simultaneously on a single logging pass.This allows selection of the frequency and spacingbest suited to specific field conditions.

HighlightsDetermine joints of casing having different weightsor wall thicknesses Locate casing collars and other casing hardware Locate evidence of casing erosion and identifydefects as being either internal or external (insidestring only) Locate holes greater than 2 in. (51 mm) in diameter Locate the bottom of outside casing strings

BenefitsIdentification and quantification of general corrosionIdentification of general corrosion in multiple casing strings


The Digital MagnelogSM service is an electromagneticmultifrequency, multispacing casing inspectionservice used to detect wall thickness changes insingle or multiple casing strings.


Length 23.83 ft 7.264 m






DMAG amplitude plot

Multi-Finger Imaging Locates Worn or Corroded Areas

ICL – Imaging Caliper Log

Analyze Casing Wear

Baker Atlas4-22 Reservoir and Production Services: Pipe Evaluation Services Catalog Version 2.1; August 2008

OperationThe range of multi-finger imaging tools provides high-resolution detail on the condition of downhole tubulars.Each tool in the family uses an array of hard-surfaced fingers which measure very small changes in diameter. Allfinger measurements are transmitted to the surface for real-time output at maximum log resolution. The pressureexerted by each finger is in the range of 1-1.5 pounds (4.4to 6.7 N) of force. This allows the tools to be deployed inchrome or plastic-coated tubulars minimizing the possibilityof damage to the coating. Additionally, this light pressuredoes not scratch standard casing, eliminating a potential forcorrosion to start.

HighlightsAssess casing wear during extended drilling operations Locate holes, casing wear and other interior defects Perforation mapping Scale evaluation

BenefitsDetermine wear profile for remedial actionUnique centralized measurements for improved accuracy

Specifications

A range of calipers for different applications and downholetubular sizes are available. Tools are available with either24, 40, 60 or 80 caliper arms. Please contact your BakerAtlas representative for specific information.

Imaging calipers show when casing is in serviceablecondition or indicate the need for remedial action bylocating any worn and corroded areas or holes in thecasing. The imaging caliper is of particular value whendrilling operations have been carried on for an extendedperiod of time through the casing string, potentiallyreducing the casing strength. Measurements can alsodetermine whether sufficient casing strength remains to conduct safe well stimulation operations. Finally,imaging caliper services can help identify potential casing leaks which may be causing high water cut orreduced production.

Cement EvaluationPipe Recovery

5. Completion and Mechanical Services

V

Baker Atlas5-2 Completion and Mechanical Services: Cement Evaluation Services Catalog Version 2.1; August 2008

Cement evaluation tools ensure hydraulic isolation between reservoir layers by measuring the bond between the casing and the cement pumped in the wellbore annulus. Before final well completions are made, the zonesbeing completed must be analyzed for hydraulic isolation to prevent possible crossflow between reservoir zonesbehind the casing. Cement evaluation logs provide results to confirm zonal isolation and help you decidewhether remedial work is required before any completions are attempted.

Baker Atlas’ Segmented Bond Tool (SBTSM) service, Radial Analysis Bond Log (RALSM) service and AcousticCement Bond Log (CBL) service provide detailed evaluations of the cement bond to casing and formation in awide variety of pipe sizes and borehole fluid environments. These evaluations reduce uncertainties regarding the quality of the hydraulic isolation of zones of interest allowing more efficient completion operations whileprotecting the environment.

More in-depth information for each service is available on the Baker Atlas website or in the Baker AtlasSegmented Bond Tool (SBTSM) brochure. Please contact your local customer service representative, or log on to www.bakeratlasdirect.com for more information and a complete list of Baker Atlas services.


Technology

Segmented Bond Tool Radial Analysis Bond Log Acoustic Cement Bond Log

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Cement Evaluation

Quantitative Analysis of Cement Bond to Casing in 60º Segments

Provide 360º Segmented Evaluation of Cement Bonding

SBT – Segmented Bond Tool

Baker Atlas 5-3Completion and Mechanical Services: Cement EvaluationServices Catalog Version 2.1; August 2008

OperationThe acoustic transducers are mounted on six pads positioned incontact with the interior casing wall to provide compensated attenuation measurements. Acoustic attenuation is measured in two directions, using an arrangement of two transmitters and two receivers on four adjacent arms. The two measurements are combined to derive a compensated value that does not depend on receiver sensitivities or transmitter power. This measurement processing is repeated for each of the six segments.

The SBT service offers significant operating advantages over conventional and pulse-echo tools due to its insensitivity to heavyor gas-cut borehole fluids, fast formations, temperature and pressure variations, and moderate tool eccentering.

For ease of interpretation, the SBT measurements are displayedin two log presentations. Both presentations are available in thelogging mode as the SBT data are acquired, processed and plotted in real time. The secondary presentation consists of six60° segmented arrays, variable-attenuation cement map and atool orientation trace overlay.

HighlightsProvide quantitative analysis of cement bond to the casing in60° segments around the borehole Provide 360° evaluation of cement bonding Identify intervals of uniform bonding and detect cement channels or voids Perform accurate, high-velocity (fast) formation cement evaluation Evaluate multiple-size casing strings on one logging pass

BenefitsAvoid unnecessary squeeze jobs Identify channels to remediate to maintain production


The Segmented Bond ToolSM (SBTSM) service quantitativelymeasures the cement bond integrity in six angular segmentsaround the casing. The SBT service can find and define channelsin the cement annulus which could result in a poor hydraulicseal. Conversely, the SBT service can reliably find zones of uniform bonding over only a few feet of casing. Under conditionswhere a short-bonded interval produces an adequate hydraulicseal, unnecessary squeeze jobs can be avoided.







The SBT log identifies a wide range ofcement bond conditions as indicated for theinterval X580 to X740. Partial bonding isidentified from X600 – 88 and X714 – 28,but there is sufficient cement present to provide hydraulic isolation.

Attempts to improve the cement conditionbetween X688 and X714 would most likely be unsuccessful because adequate hydraulicisolation exists above and below this interval,limiting the amount of cement that could besqueezed into this zone.

The two quality curves, DTMN and DTMX, indicate good pad contact with the casingwall and that the tool is properly centralized.

*Contact your

Baker Atlas

representative

for additional

series.

360º Evaluation of Cement Bond Simplifies Interpretation

Provide 360º Evaluation of Cement Bonding

RAL – Radial Analysis Bond Log

Baker Atlas5-4 Completion and Mechanical Services: Cement Evaluation Services Catalog Version 2.1; August 2008

OperationThe RAL service simplifies interpretation by displaying thefull 360° circumference of the surveyed casing section witha graphic, two-dimensional map. It immediately highlightsthe location and extent of any cement channels present.Because the RAL service provides more information in ahighly usable format, well operations can continue andremedial efforts can begin with complete confidence.

The service can be run with an optional gamma ray and neutron tool to improve correlation, and includes a temperature probe.

HighlightsProvide 360° evaluation of cement bonding Identify channels accurately in fast formations Determine annulus cement strength Detect presence of microannulus

BenefitsAvoid unnecessary squeeze operationsMaintain production, avoid water production from channels

Specifications – Series 1426 XA

The Radial Analysis Bond Log (RALSM) provides improvedcement evaluation capabilities compared to conventionalcement bond logs. The RAL service combines 8 radiallydistributed receivers with a 5-foot (1.5 m) receiver toprovide detailed analysis of casing formation bonding.The results are immediate and easily interpreted by the customer.


Length (w GR/N) 20.6 ft 7.6 m




111/16" diameter instruments and instruments with temperature ratings up to 500°F

are also available. Please contact your Baker Atlas service representative.

The RAL log presents vital cement information in an easily understood manner. The log aboveclearly shows excellent cement bond over most of the middle 400 feet. Poor cement is also shownabove and below this interval.

Determine Effectiveness of Cement Bond in Casing/Formation Annulus

Avoid Costly Production Losses

CBL – Acoustic Cement Bond Log

Baker Atlas 5-5Completion and Mechanical Services: Cement EvaluationServices Catalog Version 2.1; August 2008

OperationPart of the log presentation is a recording of the reflectedacoustic waveform either as a half-wave or full-wave(Signature) or a Variable Density display. These waveformsare used to identify the wave path and confirm the interpre-tation of the Amplitude Curve. When complete bonding isindicated, the through-the-formation wave is identifiableand can be used much like the openhole acoustic log.

HighlightsDetermine effectiveness of cement bond in casing-formation annulus Identify areas of zonal isolation Detect presence of microannulus

BenefitsCement quality indication from Variable Density log andamplitude measurements Quantitative estimate of cement strengthAvoid costly production losses or unnecessary remediationSmaller diameter for tubing and small casing sizes

Specifications – Series 1412 XA*

The Acoustic Cement Bond Log (CBL) is a valuablesource of data pertaining to the effectiveness of thecement sheath surrounding the casing. This data isobtained by evaluating the effect of the casing, thecement sheath, and the formation on an acoustic waveemanating from the Acoustic Cement Bond Log instru-ment. The Amplitude Curve of the reflected acousticwave is maximum in unsupported casing and minimumin those sections in which the cement is well-bonded tothe casing and the formation.








The CBL log clearly shows well-bonded cementbelow X440, ensuring hydraulic isolation acrossthe interval. Strong formation arrivals shown inthe VDL display indicate good cement-to-formation bonding.

Partial bonding is indicated above this point, indicating either weaker cement or potential channels. A cement squeeze could be required ifwater producing intervals existed near a productiveinterval above X440. Alternatively, a SegementedBond Tool log should be run to better evaluate this interval.

Overview of Pipe Recovery Operations

Baker Atlas5-6 Completion and Mechanical Services: Pipe Recovery Services Catalog Version 2.1; August 2008

Pipe Recovery

The following is an overview of the general steps thatshould be performed during a pipe recovery operation.

Analysis of Downhole ProblemDetermine the well configuration and events that led to thestuck pipe condition. Work the pipe and establish a stretchreading. After sufficiently working the pipe, obtain a freepoint reading which is available with the Baker Free PointIndicator series of downhole tools.

Backoff or CutAfter determining the free point, backoff or cut the pipe andremove the free portion from the well.

Fishing After retrieving the free pipe, re-enter the well to “jar” looseor wash over the remaining pipe. For expediency in certaindrilling operations, the remaining pipe can be sidetracked toreach the desired total depth.

Portable Free Point SystemSurface readouts of free point tool measurements are provided by a Free Point Indicator panel. This portablepanel and free point equipment may be used with any electric wireline and hoist unit to run free point, string shotor cutter services. Safety is assured through direct commu-nication with the rig floor and the three-stage firing circuitto arm and detonate the backoff or cutter devices.

Guardian SystemThe Guardian system incorporates downhole circuitry andan exploding-bridge wire detonator to prevent accidental firing caused by a wide range of stray voltage sources. TheGuardian system is designed for use with chemical and jetcutters, string shot backoffs, jet circulation perforators andsetting services. For more information on this service, seethe perforating section of this catalog or contact your localBaker Atlas service representative.

Pipe can become stuck during drilling and workoveroperations even when preventative measures havebeen taken. When a problem occurs, special tools and expertise are required to avoid expensive, time-consuming trial-and-error fishing operations. Throughyears of research and worldwide experience, BakerAtlas has developed advanced wireline and pipe con-veyed techniques to ensure efficient and economicalpipe recovery.


Acoustic Measurements Accurately Indicate Severity of Stuck Conditions

PRL – Pipe Recovery Log

Continuous Record and Evaluation of All Stuck Intervals

Completion and Mechanical Services: Pipe Recovery

OperationAcoustic pulses initiated by the instrument’s transmittertravel through the pipe string and are measured at thereceiver. The energy level of the acoustic waves at thereceiver is proportional to the degree of sticking. Similar toconventional cement bond log measurements, low attenuationreadings indicate free pipe and high attenuation readingsindicate stuck pipe.

Vibrations created by the pulses decrease at stuck intervalsin proportion to the severity of sticking. Both the downholeinstrument and the surface equipment utilize solid-stateelectronics to ensure efficient operations.

The downhole instrument is calibrated in free pipe, normally near the end of the surface pipe or cased interval.After recording, a signal attenuation scale is placed on thelog. This scale, expressed in percentages, accurately indicates the severity and extent of the stuck conditions at each interval.

HighlightsProvides complete record of all stuck intervals and areasof possible restrictions, including length and severity Evaluates stuck wash pipe, casing, tubing, and liners Assists in decision to sidetrack or abandon Indicates where the pipe is stuckShows whether bridges have formed in the annulusbetween tubing and casing

Specifications – Series 2510/2511*

The Pipe Recovery Log uses acoustic measurementtechniques to provide a continuous record and evalua-tion of a stuck pipe string. This logging service can beperformed through drillpipe, casing or tubing to identifyproblem areas.


Length 15 ft 4.7 m

Diameter in/mm 1.75 1.38 44.5 34.9

Pressure Rating psi/MPa 13,000 20,000 89.6 137.9

Temperature 350º F 400º F 177º C 204º C

Weight (varies) 40 lb 30 lb 18.1 kg 13.6 kg

*Contact your Baker Atlas representative for additional sizes.

The Pipe Recovery Log provides a continuousrecord of all stuck intervals and areas of possiblerestrictions. These data are very useful in planningthe pipe recovery and subsequent fishing operations.

100 90 80 70 60 50 40 30 20 10 0

Stuck Pipe Interval

X500

X600

X700

X800

Sticking Condition Increases

Percent Signal Attenuation

Pipe Collar

Locate Free Point of Stuck Point

Motorized Anchor Assembly

FPI – Free Point Indicator


OperationThe Anchor Free Point Indicator instrument detects themovement of a pipe string as the pipe is stretched, compressed,or torqued. No movement is an indication of stuck pipe.

The system is initially calibrated in free pipe to obtain anindication of the percent of pipe freedom in digital form. A direct-reading digital counter is utilized as a surface indicator. Following instrument calibration, no further adjustments are required during the course of the survey. A motorized anchor assembly retracts enabling the instru-ment to pass freely through the pipe. The assembly extendsto hold the instrument securely in place during the time thatreadings are made. Precise positioning of the instrument isaccomplished by use of a Collar Locator.

After the free point has been found, the FPI system can beused to separate the free portion of the string from the stuckportion. One procedure utilizes the FPI instrument to detonatean explosive force at the collar while applying left-handtorque at the surface. The explosive force is intended toloosen the connection so that backing off the connectionseparates the string. If this procedure proves to be unsuccessfulor impractical, jet or chemical cutters, or severing tools canbe used to sever the pipe.

HighlightsDetect free pipe in drillpipe, drill collars, BHA, tubing FPI combinable with string shot

BenefitsDetermine where to severe pipe Save time fishing stuck pipe

Specification

The Free Point Indicator (FPI) instrument is part of asystem used for recovering free drill pipe/casing/tubinglocated above the stuck portion in a borehole. The pri-mary function of the instrument is to find the free point;i.e., the downhole location where the drillstring, tubularor casing is not stuck. After the free point has beenfound, there are several methods to separate andrecover the free section from the stuck section.






Free Point Indicator locates the lowest point fromwhich the free portion of a stuck pipe string can besuccessfully recovered.

StringShot

SlackJoint

SensorSection

LowerAnchor

UpperAnchor

Free-pointMeasurement

Interval

Two Spring Anchors are used for Non-Magnetic Applications

Measures Both Stretch and Torque Movement in Stuck Pipe

SAFP – Spring Anchor Free Point Indicator

Baker Atlas 5-9Completion and Mechanical Services: Pipe RecoveryServices Catalog Version 2.1; August 2008

OperationUnlike the Permanent Magnetic Anchor Free Point instrumentor Magna-TectorSM Free Point Indicator, the Spring AnchorFree Point Indicator instrument uses two sets of frictionsprings instead of electromagnets for anchoring in the pipestring. As such, the Spring Anchor Free Point Indicatorinstrument operates effectively in aluminum or any other nonmagnetic pipe.

A tensional or torsional force is applied to the string of pipeat the surface and the corresponding elongation or twistbetween the two sets of springs is measured by the microcell.The readings indicate the deepest point from which a stringof pipe can be successfully recovered. A collar locator isalso run with this instrument, allowing the option of runninga string shot in combination for backing off the pipe stringin a single run.

HighlightsIdentify the pipe’s free pointSAFP combinable with string shot

BenefitsEfficient anchoring in all types of tubulars including nonmagnetic pipe

Specifications – Series 2530/2531/2532*

The Spring Anchor Free Point Indicator instrumentemploys a microcell that accurately measures bothstretch and torque movement in a stuck pipe string andtransmits the measurements through a conductor cableto a surface panel.


Length 10.3 - 11.4 ft 3.15 - 3.48 m

Diameter .63 in. - 1.00 in. - 1.63 in. 15.9 mm - 25.4 mm -41.3 mm



Weight (varies) 22 lb 10.0 kg


SlackJoint

UpperBow Spring

Section

Sensor Section

LowerBow Spring

Section


Interval

StringShot

Highly Accurate Electromagnetic Measurements of Stretch and Torque

Determine Free Point of Stuck Pipe

MAFP – Magna-Tector Free Point Indicator


OperationThe Magna-Tector instrument can be run in combinationwith the string shot-backoff service. This instrument mayalso be run through small-diameter pipe to determine thefree point in large-diameter pipe; e.g., locating casing orwash pipe free point below a spear. A collar log is alsorecorded as an integral part of this service.

HighlightsIdentify pipe free pointMAFP combinable with string shot

BenefitsAccurate identification of stuck pipe interval


The Magna-TectorSM instrument provides highly sensitiveand accurate measurements of both stretch and torquemovement in a string of stuck pipe. The measurementsare transmitted through a conductor cable to a surfacepanel. This instrument accurately locates the lowestpoint from which a string of pipe; e.g., drillpipe, casingor tubing, can be successfully recovered.









Interval

UpperMagnet

LowerMagnet

BottomMagnet

StringShot

Backoff Stuck Pipe and Release Other Stuck Hardware Such as Packers

Explosive Service Frees Stuck Pipe

BO – String Shot Backoff


OperationTo make up a proper string shot, certain factors must be determined:

1) Pipe size, weight and condition2) Depth of backoff3) Borehole fluid type and weight4) Well temperature

Factors 1, 2 and 3 are needed to determine the size of thestring shot and factors 3 and 4 are needed for the selectionof the proper fuses and detonating cord. A string shot can beconstructed that readily runs through an ID as small as ¾ in.(19.1 mm). It can also be run in the annulus to backoff thepipe from the outside.

HighlightsBackoff pipe (inside and outside) Release stuck packers or fishing tools, such as an overshotRemove corrosion from pipe Reopen existing perforations Jump collars

BenefitsExplosive backoff service to free stuck pipe – saves fishing time Release stuck well hardware – salvage well production


This wireline-conveyed pipe recovery tool uses a precisequantity of explosive detonating cord to produce shockwaves. The string shot backoff procedure involvesapplying left-hand torque to the pipe string at the neu-tral pipe weight (in neither tension nor compression).The string shot is then positioned at the predeterminedtool joint and detonated. The explosion produces muchthe same effect as an intense hammer blow and allowsthe joint to be unscrewed at the proper connection. Thestring shot backoff method has been improved throughyears of research and experience to increase operatingefficiency without damaging the pipe string.


Length (variable) 10 ft 3.05 m

Diameter 0.63 - 1.63 in. 15.9 - 41.3 mm





Flare Free Cuts Without Damaging Adjacent Tubulars

Free Stuck Pipe Without Torquing

CC – Chemical Cutter


OperationChemical cutters produce a flare-free, burr-free cut thatallows easy engagement of an overshot, reducing subsequentfishing operations time and expense bringing production backon line with minimum downtime. Since chemical cutter toolsare completely retrievable, no debris is left in the wellborethat can complicate future downhole work.

Chemical cuts do not require the pipe to be torqued up asdoes the string shot-back off. Occasionally, stuck pipe willrotate, even though it cannot be pulled, making a backoffimpossible. Under such conditions, the chemical cutter isthe recommended service. The cutter is also designed toperform effectively at high pressures and temperatures.

HighlightsTubular retrievalRated up to 400º F (204º C) for one hour and 10,000 to20,000 psi (68.9 to 137.9 MPa) depending on sizeSafe operations – torque not required Compatible with the Guardian system

BenefitsCorrosive cutter provides an instantaneous cut, free ofburrs or flares saving time required to dress fishtopPrevents damage to adjacent strings of tubing, casing ordrill pipeCompletely free of debris facilitating future downhole work

Specifications*

Chemical cutters have been used successfully in piperecovery operations for many years. The chemical cutterservice has been expanded to successfully sever awide range of coil tubing, tubing, casing or drillpipesizes in a fraction of a second without damaging anadjacent string. Recent advances in chemical cuttertechnology permits this service to cut corrosion-resistantalloy (CRA) tubulars safely and without distortion. Thecut is flare-free, burr-free and undistorted. This allowseasy engagement of an overshot without having todress the top of the fish.


Length 7 - 10.1 ft 2.13 - 3.08 m

Diameter 0.69 - 4.69 in. 17.5 - 119.1 mm

Pressure Rating size dependent size dependent


Min to max pipe ID .742 - 5.047 in. 18.8 - 128.2 mm

*Contact your Baker Atlas representative to determine the proper size for your

wellbore configuration.

Chemical cutters provide a flare-free, burr-freepipe cut, eliminating any delays or expensesrequired to dress the fish top.

Bull Plug

CuttingHead

IgnitionChamber

ChemicalCylinder

SlipSub

UpperPropellantSub

FiringSub

CollarLocator

LowerPropellantSub

Special Cutters also Designed to Go Through Tubing Restrictions

Sever Practically Any Size, Weight, or Grade of Casing or Tubing

JCS – Jet Cutter


OperationThe cutting action is produced by a circular-shaped charge.This type of cutter typically leaves a flare on the severedpipe string. To perform subsequent pipe recovery opera-tions, it might be necessary to dress the top end of the fishwith an internal mill, usually run with an overshot.

Caution should be exercised while running the jet cutter to avoid damage to adjacent tubing and casing strings and to minimize debris that could hinder subsequent wireline operations.

HighlightsSever virtually any size, weight and grade of tubing, drill pipe or casing Special size cutters to go through certain tubing restrictions such as seating nipple or packer Available to cut bull plugs, tailpipe or tubing-conveyedperforating assemblies to perform subsequent through-tubing operations Cut pipe in heavy mud Use in pipe salvage operations

BenefitsSever virtually any size, weight and grade of tubing,drillpipe or casing to complete fishing or salvage operations

SpecificationsPlease contact your Baker Atlas representative to select the correct size cutter for your wellbore configuration and environment.

Jet cutters are available for severing practically anysize, weight or grade of downhole coil tubing, tubing,drill pipe or casing. To perform subsequent thru-tubingoperations, special cutters are designed to go throughcertain tubing restrictions such as seating nipples orpackers to sever bull plugs, tailpipe or tubing-conveyedperforating assemblies.

Jet Cutter

Jet cutters typically leave a flare on the severedpipe string. To perform subsequent pipe recoveryoperations, it is necessary to smooth the top end of the fish with an internal mill, usually run with an overshot.

Locate Lost Circulation Zones and Underground Blowouts

Combination Noise (Sonan)/Temperature Log

SON/TEMP – Noise (Sonan)/Temperature Log


The Temperature/Noise (Sonan) Log combinationcan be used to locate fluid entry into the wellbore,underground blowouts and lost circulation zones.

OperationLiquid, gas or a combination of the two (single and dual-phase) have a distinctive sound when flowing throughrestrictions such as channels behind casing, perforations or casing leaks. This sound is detected and recorded on theNoise (Sonan) Log.

A series of band-pass filters separates the frequency spectrumof the sound for analysis of the individual amplitudes con-tained in each band. From model studies in the laboratoryand experience in the field, the relative energy levels in thefour bands of frequencies can be related to single- and dual-phase flow and the probable location of the flow.

Often considered to be a production logging instrument, theNoise (Sonan) Log can also be definitive in openhole whiledrilling and during completion. To aid interpretation, theNoise (Sonan) Log often is recorded in combination with aTemperature Log.

HighlightsDetermine fluid flow behind or inside casing Locate fluid flow in cement annulus channel Locate gas or liquid entry through casing leaks Locate gas/liquid interface in wellbore Determine whether fluid flow is single or dual phase

BenefitsLocate underground blowouts and lost circulation zonesfor remediation or well controlIdentify gas entry points for production planningDetermine fluid flow behind or inside casing for remediation or production planning

Specifications

To locate underground blowouts and lost circulationzones, the Temperature Log is typically run in combinationwith the Noise (Sonan) Log in pipe recovery operations.The Temperature Log provides a continuous measure-ment of borehole fluid temperature while the Noise(Sonan) Log detects the sound of moving fluids in ornear the wellbore.






Weight (varies) 11 lb 5 kg

3000

3100

3200

3300

3400

3500

3600

3700

3800

3900

4000

4100

4200

4300

4400

4500

135 140 145 150 155

TemperatureProfile

Band Pass,Line Corrected

Raw Data,Line Corrected

200-600 Hz600-1000 Hz1000-2000 Hz>2000 Hz

Perforating

6. Completion and Perforating Services

VI

Baker Atlas6-2 Completion and Perforating Services: Perforating

Proper selection of the perforating gun, as well as the conveyance and completion program, is a necessaryundertaking to complete a well to its optimum performance. Critical parameters of a perforating gun’s design orperformance can have positive or negative effects on the perforated completion. Each gun system has featuresand benefits that can be readily identified and used as selection criteria. This section lists the perforating systems,and their individual benefits and strengths as well as identifying techniques and technologies for various typesof completions.

More in-depth information for each service is available on the Baker Atlas website or in the Baker Atlas document Perforating Applications, A Solutions Guide for Perforated Completions. Please contact your localcustomer service representative, or log on to www.bakeratlasdirect.com for more information and a completelist of Baker Atlas services.



Baker Atlas 6-3Completion and Perforating Services: Perforating

Perforating Charges Overview

Wide Selection of Perforating Systems Available to Fit Any Application


Perforating Charges Overview

ChargesPredator ZXSM shaped charges are our deepest-performing perforatingseries. The Predator ZX shaped charge is a market leader in penetrationand performance. This system is designed to give superior performance for natural completions by giving more connectivity to the undisturbedarea of your formation.

Predator XPSM high-performance shaped charge is a premium line ofdeep-penetrating charges providing deep penetration past the damagedor invaded zone. This charge is tested in accordance with the rigid APIRP-19B specification. The charge is designed for use with expendablebar carrier, through-tubing expendable hollow carrier and expendablehollow carrier gun systems.

Predator XSSM shaped charge was recently developed to address theneeds for the stimulated completion. This series of shaped charges wasengineered to alleviate some of the problems encountered with fracingwhen perforating with high-end perforators. The design of these chargesoptimizes the hole size for the stimulation and keeps penetration deepenough to get past a lot of the near-wellbore damage and expose moreof the formation. Our goal was to help frac jobs become more successfuland to help our customers decrease their fracing costs.

Predator FPSM high-performance shaped charge is the new line of bighole charge providing maximum hole size in the casing for optimumtotal-open-flow-area. This charge is used with through-tubing expendablehollow carrier and expendable hollow carrier gun systems.

PredatorTM shaped charge was developed in the 1990s and launchedthe path to high-performance shaped charge technology. This charge isavailable for use with expendable bar carrier, through-tubing expendablehollow carrier and expendable hollow carrier gun systems.

Standard Deep Penetrating (DP) shaped charge is designed for reliable performance with expendable bar carrier, through-tubingexpendable hollow carrier, expendable hollow carrier and ported hollow carrier gun systems.

Standard Big Hole (BH) shaped charge provides a hole size that canbe used in expendable bar carrier, through-tubing expendable hollowcarrier, expendable hollow carrier and ported hollow carrier gun systems.

SpecificationsPlease contact your Baker Atlas representative to select the perforatingsystem and charge to fit your completion requirements.

Additional perforating information can be found in the BakerAtlas/Baker Oil Tools’ Perforating Applications and PerforatingCapabilities book.

Baker Atlas offers a wide range of gun sizes, shot density andshot-phasing options, with either deep-penetrating or big-hole perforating charges to match specific completion requirements.The criteria for choosing a particular perforating system varies. The selection can be a simple matter of economics, conveyance or anticipated well conditions. Each gun system and charge has features and benefits that can be readily identified and used asselection criteria.

API RP-19B Target opened up for measurements

Dynamic Underbalance

Dynamic Underbalance Optimization Process (DUO)

Producing Near-zero Skin During a Perforation Event

Baker Atlas6-4 Completion and Perforating Services: Perforating Services Catalog Version 2.1; August 2008

OperationsDynamically underbalanced perforating is a method of creating an immediate, but temporary, underbalance condi-tion in the wellbore to clean up the perforations without theneed of establishing traditional static underbalance conditions.This is accomplished by using the perforating assembly’sinternal volumes to manipulate wellbore pressure and flow.This method also addresses some operational constraintsthat can exist in some completion processes.

Baker Hughes has developed a customizable vent assembly(IGPV – Inter-Gun Pressure Vent) to enable the dynamicunderbalance requirements of each perforated section. Thesurge assembly creates the required pressure-drop and flow-volume based on DUO pre-job modeling.

HighlightsReduces or eliminates perforating damage and debris,near-zero skin perforationsUses custom-designed programs for each intervalSimplifies well preparation by removing the need forlarge static pressuresReduces risk of environmental impact

Baker Hughes’ Dynamic Underbalance Optimization(DUOSM) process is an analysis and job planning system to engineer the underbalance profile and flowduration during the perforation process, and optimizethe flow efficiency of the perforated completion.

Dynamic Underbalance flow characteristic

Berea core perforated, cut open and examined.

The nearly infinite combination of the number of ports opened in thevent sub and the volume of atmospheric chambers included, allows theBHA to be tailored to precisely match the reservoir requirements.

Baker Atlas 6-5Completion and Perforating Services: PerforatingServices Catalog Version 2.1; August 2008

Overcome Extensive Drilling Damage

StimGun Propellant-Assisted Perforating Products

Increase Productivity

The StimGun process maximizes connectivity by creating fractures to extend beyond the perforation tunnels.

OperationThe StimGun family of products consists of three unique product offerings – the StimGun Assembly, the StimTubeTM

Tool, and the Well Stimulation Tool (WST). These threeproducts allow for maximum stimulation design flexibilityfor a wide range of well configurations.

The StimGun assembly consists of two major components –the perforating gun and the special propellant sleeve surrounding the gun. During the perforating event, the propellant sleeve is ignited, producing a burst of high-pressure gases that enter the formation through the perforations and create fractures. The result is improvedpenetration into the formation and greater connectivity tothe wellbore.

The StimTube and WST instruments are both stimulationtools used as an efficient and economical means to providestimulation to wells having existing perforations or open-hole completions. They are conveyed on wireline and oftencan provide economical alternatives to recompletion and remediation.

An integral portion of the StimGun family of products is the pre-job design analysis from the PulsFracTM modelingsoftware. The results of the PulsFrac analysis are used todefine job parameters such as propellant quantity, fluid level requirements, pressure magnitude and duration, and to optimize the breakdown and fracture results.

ApplicationsWells with extensive near-wellbore damageWells with close oil or water contact, where hydraulicfracturing is not possiblePre-stimulation perforation breakdown to reduce tortuosity and increase injectivityTubing-conveyed or wireline-conveyed perforating applications

The StimGunTM family of propellant-based products offersthe industry the first fully integrated, technology-based,and thoroughly tested tools designed to dynamicallyclean up and stimulate the near-wellbore area.

Pre-job design analysis from PulsFracTM

modeling software.

StimTube and StimGun are trademarks of Marathon Oil Company.

PulsFrac is a trademark of John F. Schatz Research & Consulting Inc.

Drastically Reduce Debris in Extended Reach Wellbores

XLD (eXtreme Low Debris) Perforating Systems

Debris Management


Debris Comparisons

0

20

40

60

80

100

120

140

Debris from StandardSteel Charge (cc/m)

Debris fromPERFFORM low debris

system (cc/m)

New Extreme LowDebris System (cc/m)

Debris Volume (cc/m)

OperationsBaker Hughes has been an innovator and leader in low-debris technology for perforating services in completions.Once again Baker Hughes is advancing low debris technologywith its new XLD (eXtreme Low DebrisSM) perforating system introduced in 2007. This advanced system does notdegrade shaped charge perforation performance, it actuallyenhances it in some cases. The reduction of perforatingdebris volume is 92% less that of steel and 82% less that ofour low-debris PERFFORMSM systems. This significant andimpressive reduction in debris helps keep wellbores cleanerand significantly reduces debris-related issues and theiradverse effects on production.

HighlightsSignificant decrease in debris compared to current industrial low-debris standardsReduced completion problems related to perforating debrisCleaner wellboresAvailable in 33/8" and 4½" (85.7 mm and 114.3 mm)HOPS service

When perforating long intervals in extended reach wellsor where wellbore undulating is present, debris can be an immense problem. Debris can build up in lowareas in the wellbore, even in the perforations tunnels,reducing production and sometimes cutting off intervals.Clean up is very expensive and can damage zonesunder the right circumstances. The eXtreme Low Debrissystem reduces the debris volume by 92% compared tosteel charges without adversely affecting shapedcharge performance.

Reduce Perforating Debris to Enhance Operations

PERFFORM Low Debris Perforating Systems

Effective Sand Control


Comparison of shaped charge debris generated permeter of perforated interval.

Operation

Baker Hughes pioneered low-debris technology whenPERFFORM shaped charges were introduced in 1991, andit has since become the industry benchmark for low-debrisperforating. The PERFFORM perforating system utilizes ashaped charge case and a patented liner that does not producecarrots and coarse steel charge debris. The debris is reducedto a fine, acid-soluble powder, which is easily flowed back.As a direct result of the smaller debris-size distribution, theprobability of plugging is significantly reduced.

The debris from the shaped charge case is soluble tohydrochloric acid at standard concentrations and also to the newer high-temperature organic acids.

The result is a cleaner, more productive gravel pack completion.

HighlightsElimination of carrots Smaller debris sizeIncreased solubility to acidReduced completion problems related to perforating debrisCleaner wellbores and perforationsEnhance formation treatmentCompatible with most completion fluidsAvailable in deep penetrating versions for natural completions and extended reach applicationsAvailable in all shot densities and all gun sizes

Big-hole or “gravel pack” shaped charges use linerswhich, after perforating, re-form into solid plugs of coppercommonly called “carrots.” Carrots and other chargedebris can plug perforations and cause stimulation andcompletion techniques to fail, leading to increased costsand reduced operational efficiency. Plugged perforationsmight not be successfully packed, reducing effectiveshot density and possibly creating a potential for gravelpack failure. PERFFORM SM shaped charges providelow debris, carrot-free perforating operations.

Comparison between PERFFORM low debrisshaped charge (left) and debris generated from a standard shape charge.

INSOLUBLE

97 %

INSOLUBLE

22 %

SOLUBLE

78 %

SOLUBLE

3 %

PERFFORM STEEL

7" OD

12 SPF GP

4-1/2" OD

12 SPF GP

0.0 5 10 15

Kg/meter

Standard Perforator

PERFFORM Low Debris

PERFFORM STEEL

PERFFORM debris is acid soluble compared to standard charge debris.


Larger Perforating Guns for Restricted and Gas Wellbores

XPLS – 2" and 21/2" Low Swell Guns

Thru-Tubing Perforating in Gas and Restricted Profile Wellbores

OperationsThe 2" Predator XP LS is for conditions requiring betterperformance in a well having restrictions that typically mandate the next lower size gun system. Bigger is better, in that the bigger the charge the better performance it has.The smaller gun systems, 19/16" EHC, drastically reduce the perforation hole in a well, thus possibly reducing the potential for the well. This is nothing new – a larger gundown the wellbore leads to better penetration performance.

HighlightsPremium shaped charge with deep penetrationLow swell design means the spent gun can pass throughtighter restrictionsReduction in debrisCan be mixed-loaded with the Predator XSSM

shaped chargesField proven with hundreds of runsAvailable in 2" and 2½" Predator XP shaped chargesPerformance data available at www.api.org

The 2" and 2½" Predator XP Low Swell (LS) gun systems are a breakthrough in performance and debrisreduction for a low swell system. These systems exceedanything in low swell on the market. The low swell aspectof this design was not accomplished by lowering theexplosive gram load and sacrificing performance. This featwas accomplished through new concepts and technologyin the perforating industry developed by Baker Atlas.

2" Predator XP LS charge passingthrough a 2.188" nipple after being shotin fluid.

Debris comparisons from a 2" PredatorXP LS charge (A) and a regular 2" steelshaped charge (B).


Align Perforations with the Formation Stresses

HOPS – Horizontal Oriented Perforating System

Prevent Sand Production

Perforating with respect to in-situ stress

OperationThe Horizontal Oriented Perforating SystemSM service isused to reliably perforate long intervals in highly deviatedand horizontal wellbores where accurate orientation of theperforations is critical. Additionally, Shot DirectionIndicating Devices (SDIDs) can be used throughout the gun string to provide verification the guns orient correctly.

Accurate orientation ability has been engineered into the system and verified by both extensive full-scale laboratorytesting as well as numerous field cases, even in wells havingtortuosity through the perforated interval.

HighlightsUsed in applications such as perforating to prevent sandproduction as well as perforating to avoid water contactAccurate and verifiable orientation in wells having tortuosity up to 10°/30 meter build in the perforated intervalOne recent North Sea job using SDIDs verified orientation was within 7.5° as designed.A world-record job perforated 2,246 meters of interval in one run, using 188 swivel gun connectors with 100% success.

Specifications

Oriented perforating with respect to the in-situ formationstresses has been shown to prevent the onset of sandproduction in moderately competent sandstones. TheHOPSSM service provides accurate and reliable orientationof the perforating guns in highly deviated, extended-reach wells.

Further information on HOPS and oriented perforating is found in SPE

80929, “Advances in Horizontal Oriented Perforating Optimize Perforation

Efficiency and Production While Maintaining Borehole Stability.”

Some of the shot patterns available

Horizontal Oriented Perforating System (HOPS)


Gun OD (in.) 2.88 4.50 6.00 7.00

Shot Density (SPF) 6 Various 5 10

Phasing 10°/350° Various 10°/350° 0°/180°

Charge Type Predator XP and PERFFORM DP


Perforate Without Killing the Well

Snapshot CT Live Well Deployment System

Prevent Formation Damage

OperationThis system is used with a coiled tubing unit to convey theguns and maintain well control during the entire operationwithout introducing potentially damaging kill-weight fluidto the reservoir.

Guns are deployed into the well with the Snapshot connectorusing only stabbing and pulling motions to connect gun sections. This is accomplished by the positive snap latchdesign of the connector, requiring only set-down weight tosnap the latch sub of the upper gun into the receptacle of thelower gun. The gun sections are uncoupled via a dedicatedram in the deployment BOP, which when closed, compresseskeys in the latch sub to release the connection.

To transfer the detonation from one gun section to the next,a field-proven bulkhead ballistic “wet connect” transfer system featuring a donor shaped charge is used. Upon detonation of the upper gun, the donor shaped chargelocated in the latch sub perforates the bulkhead of the transfer sub in the receptacle, and in so doing detonates the lower perforating guns.

ApplicationsUnderbalanced perforating of long intervalsThrough-tubing interventions in deviated or multilateral wellsPerforating long intervals without the need of a drilling or workover rigUnderbalanced perforating of depleted or fluid-sensitive reservoirs

Specifications

The Snapshot CTSM Live Well Deployment System is a special perforating gun system used to deploy andretrieve perforating guns into a producing well withouthaving to kill the well. By not killing the well, no poten-tially damaging kill-weight fluids are placed across the reservoir.


Tool OD (in.) 2.30 3.00

Make-up Length (in.) 37.2 34.4

Pressure Rating (psi) 20,000 20,000

Tensile Rating (lb) 60,000 75,000

Torque Rating (ft-lb) 1,800 3,100


Perforate without Killing the Well

SGS – Stackable Gun System

Prevent Formation Damage

OperationUtilizing either the special pressure set or mechanical setBottom Gun Anchor to establish a fixed bottom, the gunsare lubricated into or out of the well using slickline or wireline, one section at a time. The last gun sectiondeployed contains a TCP-style firing head. After the guns have fired, the gun sections can be retrieved one at a time without the need to kill the well.

HighlightsAdaptable for most applications• Re-perforating• Underbalanced perforating• Depleted or fluid-sensitive formations• Rigless perforating of long intervalsAvailable with mechanical or hydraulic-setCompatible with Predator XPSM perforating systemsCompatible with the StimGunTM systemWireline or slickline conveyance

Specifications

The Stackable Gun System is a special perforating system used in both new well completions and wellinterventions to perforate long intervals underbalanced.As the guns can be retrieved without killing the well, formation damage can be prevented.

Casing Sizes 31/2 41/2 5 & 51/2 7 & 75/8

Gun OD (in.) 2 27/8 33/8 41/2

Gun Lengths (ft) 4, 7, 11, 14, 21, 28

Connector M/U 0.97 0.93 1.14 1.12Length (ft)

Fish Neck (in.) 1.75

Centralizer OD (in.) 2.760 3.800 4.375 5.600


Perforate Longer Intervals while Maintaining Pressure Control

IGAR – Inter-Gun Automatic Release

Increase Operational Flexibility

OperationThe IGAR is useful in applications where it is desired toretrieve only a portion of the perforating guns, such asinstances where limited lubricator length prohibits retrievingthe entire perforating assembly.

Detonation of the perforating guns creates a pressure wave that travels through the IGAR to shift a piston upward.A collet, no longer supported by this piston, is now free toretract and the guns are free to separate.

After the IGAR has released, a fishing neck profile is provided on the “left in hole” portion of the tool to alloweasy retrieval using a standard fishing overshot.

HighlightsThrough-tubing wireline perforating of intervals longerthan the wireline lubricator lengthUnderbalanced perforating of depleted or fluid-sensitive reservoirs Useful for TCP, CT and top-fire wireline conveyed perforating jobsCan be placed at any connection along the gun string

Specifications

The Inter-Gun Auto Release (IGAR) is a modularrelease tool used within the perforating gun assemblyto automatically release a portion of the perforatingguns after the guns have detonated. This feature allowsperforation of longer-length intervals on wire or coilwhile at the same time allowing simple pressure-controlled retrieval of the gun sections without the need of expensive surface deployment systems.

Size CIS

OD [Max] (in.) 3.125

Operating Pressure (psi) 20,000

Tensile Rating (lb) 40,000

Fishing Neck OD (in.) 1.375

Temperature Rating Dependent on Explosives Used

Service Standard


Tool Size 43 45 47 51

Casing Size (in.) 41/2 to 5 51/2 7 to 75/8 95/8

Pressure Rating (psi) 15,000

Load Limit (lbs) 35,000

Perforate Longer Intervals on Wireline with Fewer Runs

J-GB – Model J-Gun Brake

Reduce Completion Costs

OperationThe J-Gun Brake is a compact, economical, temporary gunanchor that minimizes gun shock to the wireline ropesocket. The J-GB is set with axial movement (up/down),and simple overpull releases the tool and resets it to therun-in position. Depending upon the requirements, the J-GBcan be assembled in either the “Compression Set Mode” toprevent the guns from being blown downward in balancedor slightly overbalanced applications, or in the “Tension SetMode” to prevent the guns from being blown upward during underbalanced perforating.

Unlike other gun brake devices that attempt to restrict or“brake” any movement after detonation, the J-GB isanchored securely before the perforating event.Additionally, the J-GB features a “Gun Shock Position” that will automatically reset if movement in the opposite direction occurs.

HighlightsPerforate longer intervals on wireline without the needfor a rig or TCPRugged and reliable construction utilizing proven Baker Oil Tools technologyCase Study: 145 feet of 41/2" OD 12 SPF perforating gunsshot in one run in BrazilCase Study: 42 feet of 7" OD 18 SPF big hole guns shotin the Gulf of Mexico in one run

Specifications

The ability to perforate multiple or long-length intervalsin one run using wireline can drastically reduce rig time,saving completion costs. With the Model J-Gun Brake(J-GB), longer and heavier guns are run in a single trip,where in the past multiple runs would have been required.This time savings can significantly reduce operatingcosts for deepwater completions.


EMO – Electro-Magnetic Orienting Perforating

Proven Technology to Avoid Perforating the Long String

Reliably Perforate the Upper Zone

OperationOriented perforating in the direction opposite the lowerinterval production string (long string) is accomplished withthrough-tubing perforating using the EMO system. Usingthe properties of electro-magnetism to detect the mass ofthe long string and incorporating a rugged downhole motorand anchor, the perforating guns can be selectively rotatedto a position to fire opposite the long string.

HighlightsFully compatible with the Guardian systemField proven technology, years of reliabilityCombinable with most perforating systems, including the Predator XPSM high-performance shaped chargesFor through-tubing applications in 23/8" and greater tubingCan be configured to perforate the long string, via the short string, for well control and pipe recovery applications

Inadvertent perforating of the long string can introducesafety and production concerns, as well as unnecessarycosts and complexities. The upper zone of a dual completion can be reliably perforated using the proven“EMO” perforating system to orient the perforationsaway from the long string.


Perforating Deviated or Long Intervals without a Rig on Location

CTCP – Coiled Tubing Conveyed Perforating

Reduce Costs for Interventions

Operation

Coiled tubing offers a number of operational and economicadvantages including: live well intervention, elimination ofwell kill and potentially damaging fluids, reduced operationalfootprint, horizontal well intervention and the ability to intervene without a rig. Its tubular construction allows aconduit for circulation and pressure control and, coupledwith the ability to install electric line into the tubing, makescoiled tubing a highly versatile conveyance method.

Baker Hughes provides perforating solutions that capturethe benefits of using coiled tubing conveyance while providing field-proven technology.

ApplicationsThrough-tubing interventionsSnapshot CTSM Live Well Deployment System for intervention without need of well killCombinable with electric wireline provides positive per-forating depth and multiple zone SelectFire applicationsPerforating of highly deviated and extended-reach wellswithout need for drilling rigPipe recovery applications such as perforating for circulation and tubing cutter operations

Highlights1,455 feet (443 meters) of 2" OD x 6 SPF perforatingguns conveyed in one run successfully perforated and retrieved758 feet (231 m) of 19/16" OD x 4 SPF perforating gunsconveyed in one run successfully perforated and retrieved

Perforating of highly deviated wells without need for adrilling rig on location can reduce costs significantly.Coiled tubing provides an efficient and cost-effectiveconveyance method of perforating guns. Coiled tubingprovides the rigidity necessary to place perforating gunsin extended-reach wells, and has the needed the strengthto run longer-length gun assemblies compared to conventional wireline conveyance.


Save Time on Well Completions

NeoTrip – One-Trip Perforate and Completion Systems

Proven Cost Savings

System Firing Option Anchor Option

Neo-Trip HH Hydraulic HBGA

Neo-Trip PH Passive HBGA

Neo-Trip RH Redundant HBGA

Neo-Trip MJ Mechanical JBGA

Neo-Trip RHR Redundant HR

OperationLeveraging expertise from all Baker Hughes completionstechnologies, the NeoTrip completion systems present a true “one-trip” perforate and completion solution that is fieldproven. The well is perforated after the completion, and production equipment is in place and flanged up, so produc-tion can be brought on immediately.

HighlightsUtilizes the Hydraulic Bottom Gun Anchor (HBGA), the Model J Bottom Gun Anchor (JBGA), or the Hangand Release Gun Hanger (HR) to provide a temporaryplatform to secure the guns on depth.A selection of firing methods includes pressure or mechanically actuated, redundant pressure-fire, and slickline-conveyed passive systems. The gun assembly is run as the bottom-most portion ofthe completion. After setting the anchor to secure the gunsat shooting depth, the completion string is separated fromthe bottom-hole assembly and repositioned to the desiredsetting depth. The wellhead can be installed.The completion string can be set as far uphole from the perforating guns as desired. This allows future completions without tailpipe interference.After firing, the perforating gun assembly automaticallydrops to bottom, providing fullbore access.Systems available for 41/2" casing through 95/8" casings.

Sample Configurations

The benefits of a successful “one-trip” style completioninclude saving rig time and minimizing fluid losses. TheNeoTripSM series of one-trip completions have beenproven in the Gulf of Mexico and other regions to successfully provide novel solutions that save time and offer flexibility.


Save Rig Time and Reduce Fluid Loss

PDP – Perforate and Gravel Pack Completion System

Simplify the Gravel Packed Completion

OperationLeveraging expertise from all Baker Hughes completionstechnologies, the PDP system presents a field-proven, “one-trip” perforate and gravel pack solution. The perforating and gravel pack operations are conducted after the completion equipment is flanged up; productionbegins immediately thereafter.

The gun and screen assemblies are run in on the completionstring with either the Hydraulic Bottom Gun Anchor (HBGA)or the Model J Bottom Gun Anchor (JBGA) to provide atemporary platform. The completion string is separatedfrom the bottom-hole assembly and raised to the desired setting depth. The completion is set, and the well is flangedup. The guns and screen drop immediately after firing to the pre-determined PBTD; the screens are now across theperforations. A simple over-the-top-style frac pack is thenperformed, and the well is brought on production.

HighlightsOver 15 successful runs to date in the Gulf of Mexicoand Asia Pacific regions (2003)Systems available for 41/2" casing through 9 5/8" casingDetonated by either mechanical or hydraulic meansCombine with StimGunTM to reduce the perforation breakdown pressures Combine with the TCP Firing Head Setting Tool to runand set the plug on the same trip

The PDP Perforate and Gravel Pack Completion Systemcombines proven TCP and sand control technologies.This “one-trip” gravel pack completion provides benefitssuch as reduced rig time and fluid loss for wells not requiring a complex gravel pack procedure.


Directional Perforating with Respect to the Fracture Planes

TCP-AOP – TCP Azimuthally Oriented Perforating

Reduce the Fracturing Costs

OperationThe perforating guns are aligned with the oriented-indicatingsub, which is placed above the firing head and ported discassembly. Once the guns are on depth, the gyroscope is conveyed on electric line and seats in the oriented indicatingsub. With real-time reading provided by the gyroscope, rotating the pipe at the surface aligns the perforations to the desired azimuth.

HighlightsPositive orientation for proper alignmentReduces costs involved with stimulating the wellIdeal for vertical wells Verifies proper alignment prior to perforatingSystems available for all tubing sizes

For reservoirs requiring stimulation, orienting the perforations to the fracture plane helps reduce thebreakdown pressure. A novel TCP method allows perforations to be azimuthally oriented using a gyroscope and a properly aligned oriented-indicatingsub. This method provides real-time verification of the orientation prior to perforating.


PSI – Parallel Perforating System

Reduce the Costs Associated with Stimulating Multiple Zones

Stimulate, then Perforate, in a Single Run

OperationsThis system offers a unique approach by stimulating a lowerzone, and then moving up the hole to perforate the nextzone. The perforating gun and firing head assembly areside-mounted to the workstring, providing non-restrictiveflow during the stimulation process.

To perforate, a pump-through plug is dropped from the surface seats, isolating the hydraulic firing head. Pressure isthen applied to fire the gun. Additional pressure ruptures thedisc in the plug to reestablish circulation.

HighlightsSpecial TCP application for stimulating zones andthen perforatingAllows rotation of the workstring for setting packers or actuating accessory toolsSafe and reliableUnlimited number of intervals may be treated Field provenMay be used in any deviation

Specifications

In highly deviated wells requiring staged stimulations,numerous runs are necessary: one trip to perforate and one trip to stimulate. The PSI Parallel PerforatingSystem, a special TCP application, incorporates a perforating assembly with the workstring. Using thissystem, the zones are stimulated then perforated in asingle run, thus reducing the number of runs required.

System Size 7-inch OD casing

Gun OD (in.) 27⁄8

Shot Density (SPF) 6

Phasing 60º/240º

Max Torque (ft-lb) 5,000

Max Tensile Strength (lb) 180,000

Pressure Rating (psi) 15,000


Save Rig Time and Tailor the Completion of Each Zone

Tubing-Conveyed Dual String Perforating Systems

Reduce Cost and Increase Efficiency on Complex Completions

OperationTubing-conveyed perforating offers flexibility and adapt-ability for multi-zone, single-selective and other complexwell completion designs. Combining the TCP as part of thecompletion string reduces rig time and enables the well tobe brought on production immediately after perforating. Bynot killing the well to retrieve the spent perforating guns,potentially damaging fluids are not required.

Inadvertent perforating of the long string can introduce safety and production concerns, as well as adding costs and complexity. Perforating in the direction opposite theproduction string is accomplished by using specially-configured TCP perforating guns and hardware that maintain orientation during the trip in the hole.

HighlightsTCP systems for dual-string applications in most casing sizesMaximum underbalance to promote effective perforation clean-upImmediate production without killing the wellCombinable with most guns, including the Predator XP SM

high-performance shaped chargesApplicable for multiple, fluid-sensitive and depleted intervals

Multiple zones can be individually isolated and perforatedaccording to the optimum completion program for eachreservoir. Zones can be perforated underbalanced,overbalanced, or with specialized fluids to best optimizeproductivity. Tubing-conveyed perforating guns areinstalled as part of the completion and positioned toperforate away from adjacent production strings, reducingtime and increasing operating efficiency.


GDN – Guardian II/EBW Perforating Package

Perforating Using Electrical Devices

Wireline Perforating Safety


Temperature -13º F to +437º F (-25º C to +225º C)Rating (°F)

Input 22-230 VDC @ 160-260 mA

Output (Firing) 5000 V+15% / >2000 A / <250 nsVoltage

Pressure Rating Dependent on the gun system

OperationThe Guardian II system consists of two main components:the exploding bridgewire (EBW) detonator and electronicmodules known as the PX-1.

The EBW detonator does not contain a primary explosiveand is immune to initiation by external power sources.

Activating the PX-1 module causes a capacitor to chargeand release the stored electrical energy into the bridgewirewithin the EBW detonator. This time-dependent energyrelease causes the bridgewire to explode into the secondaryexplosive of the detonator thus beginning the high-orderexplosive process.

HighlightsAvailable for all perforating gun sizesAvailable for both bottom-fire and top-fire systemsAvailable for packer setting tools and pipe recovery applicationsField-proven technology, years of reliabilityEliminates the need for any of the following during theperforating process:• Radio silence• Shutdown of cathodic protection• Shutdown of welding process

Specifications

The Guardian II system is a ballistic fire control systemspecifically designed for perforating safety. This systemeliminates the need for radio silence, shutting down ofcathodic protection, or welding during the perforatingoperations. In areas where remote reporting sensorsand transmitters are used, the Guardian II system iscritical to ensure safety.

Wireline Conveyance SystemsRisk-Reduction Technologies

7. Deployment Risk Management

VII

Baker Atlas7-2 Deployment Risk Management: Wireline Conveyance Systems

Getting In and Out of the Hole Safely

Wireline Conveyance Systems


Some of the most important aspects to consider during the design, construction and productive life of a well arethe risks associated with the conveyance of downhole instruments to acquire critical formation evaluation datawhile the hole is open, and the downhole toolstrings needed to service the well after installing the completionand production hardware.

As it became more difficult to discover large oil and gas fields in relatively shallow and friendly environments,the industry stepped out into more complex and less familiar territories requiring the creation of new technologiesand methods designed to drill, complete and produce longer, deeper and more deviated and tortuous wells.

The increased complexity of the wells increased the aggregated cost of all well interventions. In particular, therig cost resulting from the time required for these operations became a point of serious concern when planningthe well intervention operations.

The applicability of the different conveyance systems depicted in the table below is based on practical experience,and is intended as a guideline only. The following pages provide more specific details on the attributes of thespecific conveyance methods.


Technology

Unassisted Wireline Pipe Conveyed Logging/Perforation Tractor Conveyed Logging/PerforationCoiled Tubing Conveyed Logging/PerforationPump Down Conveyance

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PCL – Pipe Conveyed Logging

Baker Atlas 7-3Deployment Risk Management: Wireline Conveyance Systems

Drillpipe Assisted Wireline Interventions

For Extreme Operations in Highly Deviated or Tortuous Well Paths


Operation

The logging instruments are attached to the bottom of the drillpipe prior to running in hole to a latching depth. A side-entry sub is then inserted at the surface with the wireline already threaded through it, which is subsequentlyrun in hole until a mechanical and electrical connection isestablished with the downhole tools via the wet-connectand tool adapter. The drillpipe and wireline are then synchronously moved in and out of the hole as needed to perform the intended logging operations.

HighlightsAllows logging of all Baker Atlas tool combinations Can be connected with all drillstring types, directly orvia adapter subsAllows multiple wet connections while logging morethan one interval without tripping pipe out of the holeCapable of logging while going in and out of the holeafter an electrical latchCan be used with a motion-compensated system onsemi-submersible platformsDisplays real-time cablehead compression and tension readouts

Benefits

The PCL is most frequently requested when:The well deviation exceeds the limit of the instrument’sfreefall (~ 65 deg).Difficult hole conditions are expected, i.e. boreholeswith washed-out sections, ledges, restrictions or excessive doglegs.The customer elects to reduce the risk of failing to reach the target depth or having insufficient wirelinepull capacity, such as in 20,000 ft (6,096m) or longerboreholes where heavy toolstrings are required.

The Pipe Conveyed Logging (PCL) system allows logging wireline toolstrings in wells with conditions not suitable for unassisted wireline operations, i.e. tortuous well paths, highly deviated, horizontal orwashed-out holes.

Wet Connect and Tool Adapter assemblies

Major components of the Pipe Conveyed Logging system

Description PCL-D PCL-E PCL-F PCL-G PCL-H PCL-I

Diameter 33⁄8 in. (86 mm) 5 in. (127 mm) 23⁄4 in. (70 mm) 33⁄8 in. (86 mm) 5 in. (127 mm) 5 in. (127 mm)

Pressure Rating 20,000 psi 20,000 psi 30,000 psi 30,000 psi 30,000 psi 30,000 psi137.9 MPa 137.9 MPa 206.8 MPa 206.8 MPa 206.8 MPa 206.8 MPa

Temperature 350º F (177° C) 350º F (177° C) 400º F (204° C) 400º F (204° C) 400º F (204° C) 400º F (204° C)

Add-ons Flow ControlValve

Specifications

This downhole tractor is configured with twotraction sections offset 90 degrees that include fourhydraulically driven wheels each.

Downhole tractors are configured to pull large enough forcesto keep the wireline in tension while pushing the toolstring.

WTCL – Tractor Conveyed Logging

Baker Atlas7-4 Deployment Risk Management: Wireline Conveyance Systems

For Fast Operations in Highly Deviated Wells

Tractor Assisted Wireline Interventions


Operations

Downhole tractors are electrically powered devicesthat are inserted between the wireline and the passenger toolstring. Under the control of the operator, they can be activated to push passengerdevices while pulling the wireline to the desireddepth in highly deviated or horizontal wells.

There are two distinctive traction methods currently used by tractor makers:

Motorized wheels, mounted in extendable arms,that grip the inner borehole wallFriction pads mounted in arm assembliesattached to the ends of a reciprocating piston.Alternating the opening and closing of the armassemblies in each piston stroking cycle createsan “inch-worm” type of movement.

HighlightsDo not require a rig in placeTractors and surface equipment can be transported easily.The leading tractor models have long and successful track records in cased hole applications.Long-reach or tortuous-path tractor applicationsrequire careful planning and physical tests usingthe exact tractor-toolstring configuration in representative tubulars.

BenefitsReduce the cost of well interventions significantly,and in some cases, offer unique conveyancesolutions by extending the operating range ofconventional wireline into high-angle and horizontal wells. Many additional uses have emerged for tractorssince their introduction in the mid-90s; leadingtractor providers offer add-on devices such asheavy-duty shifting tools, milling and cleaning heads.

The use of downhole tractors allows fast andcost-effective well interventions to be carriedout in high-angle and horizontal wells wheretraditional conveyance methods require significantly more rig time, rig space, crews or highly complex operations.

Baker Atlas 7-5Deployment Risk Management: Wireline Conveyance Systems

For Operations in Highly Deviated Wells

Coiled Tubing and Flow Assisted Wireline Interventions


CTCW – Coiled Tubing Conveyed Logging

Operation

Coiled tubing is used to push the toolstring to the desireddepth in highly deviated or horizontal wells while the wireline embedded in the CT provides the electrical path for downhole power and data transmission.

HighlightsRequires large/heavy CT units and a large specialized crew Has a limited-reach rangeLarge-diameter CT is not suitable for small ID completionsNeeds specialized equipment:• CT logging heads• Depth encoder CT adapters• Wireline collector rings CT adapters

Coiled tubing (CT) containing an electrical wireline provides an effective alternative in well interventionstargeting high-angle and horizontal wells where otherconveyance methods are not technically or economically viable.

The CT is used to convey the logging toolstring in andout of the hole while the wireline embedded in it provides the electrical power and communication path.

TDP – Pump Down Conveyance

Operation

The toolstring is run in the hole as deep as possible usingwireline. When it stops, fluid is pumped in the well at a ratecalculated to create enough hydraulic force on the toolstringto push it to the target depth.

HighlightsNo additional equipment is required. Toolstring OD is limited by the ID of the tubulars.Toolstring pistons are typically manufactured onsitebased on the given conditions. Requires an open circulation path in most cases

BenefitsIn some cases, it is the only method capable of reachingthe intended depth.The preferred choice in pipe recovery operations, i.e. freepoint, pipe cutters.

The ability to pump down fluid while running in holetoolstrings attached to a wireline provides a fast andeffective means of reaching highly deviated or horizontalsections of a casing, tubing or drillpipe.

To ensure the toolstring reaches the target depth,piston assemblies are mounted on the string tomaximize the hydraulic forces exerted by the fluidbeing pumped.

BenefitsDoes not require a drilling rigSuitable for high-angle or horizontal wellsProvides extra protection to the wirelineWell-suited for operations in live wells

Baker Atlas7-6 Deployment Risk Management: Risk-Reduction Technologies

Modern Well Interventions Demand Innovative Techniques

Risk-Reduction Technologies


Some of the most effective and popular technologies availabletoday are illustrated in the diagram at the left and their valuesprovided below:

1. Wireline-Forces Modeling – Modern modeling softwaretakes the guesswork out of predicting the forces exerted on the tools, the borehole and the wireline during well interventions at all depths.

2. Wireline Tension-Relief Devices – These devices avoid the safety hazards associated with high tension exerted on the wireline.

3. High-Strength Wirelines – These wirelines can be usedto safely deploy heavy toolstrings in deep wells while retainingsufficient overpull capacity.

4. Releasable Cableheads – Allow wireline operations with-out downhole mechanical weakpoints that limit the downholepull capacity.

5. Wireline Jars – They are a very effective means of avoidingstuck-tool or fishing operations.

6. Low-Friction Roller Stand-offs – They ease the descentin deviated holes while reducing the risk of differential sticking.

7. Advanced Hole Finders – They are designed to overcomeborehole anomalies, such as ledges, abrupt directionalchanges, debris, etc.

Over the recent years, technologies have been introducedthat eliminate or mitigate the risks that jeopardize safe andfast wireline well interventions in modern, complex wells.

Primary Application

Reduce the number of runs Avoid differential sticking Avoid high tension hazardsHelp reaching target depthIncrease downhole pull capacity

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CERB – Well Intervention Modeling Services

Baker Atlas 7-7Deployment Risk Management: Risk-Reduction Technologies

Modeling Forces for Planning and Performing Wireline Operations

Wireline Well Intervention Planning


OperationA model is built based on the well geometry, trajectory,temperature profile, properties of the fluid in the hole,toolstring and wireline physical specifications.The model is then used to simulate the well interventionunder planned and contingency conditions, such as astuck tool.The forces calculated during the simulations are thenassessed against a set of pre-defined boundary limits toflag potential hazards.

BenefitsAllows the characterization of the magnitude and natureof deployment risks present in complex well interventionsearly in the well-construction processIt is the most-effective tool for:• Well intervention feasibility studies• Risk-benefits intervention analyses• Well intervention contingency planning• Toolstring optimization• Wireline and weakpoint selection• Flow and pressure effects assessments• Managing stuck tool and fishing operationsWhen used at the wellsite, it helps manage complex well interventions.

Modern modeling software takes the guesswork of theprediction of the forces exerted during well interventionson the tools, the borehole and the wireline at all depths.

These diagrams depict two of the many principleson which modern wireline forces-modeling softwareis based.

This surface weight graph depicts an intervention planned in a well with the trajectory shown at the right. The modelingsoftware predicts that the expected pull-out-of-hole surface tension (green curve) will exceed the wireline manufacturer’ssafe working load – illustrated by the red vertical line.

Deviated & Friction Effect

Cable or Tool Segment

Hole Wall

Dogleg Effect

Continued on next page

CERB – Well Intervention Modeling Services (continued)


Modeling Forces for Planning and Performing Wireline Operations

Wireline Well Intervention Planning


Tension Simulation – At DepthForce analysis with the toolstring at a specified depth, i.e.pulling on a stuck tool, negotiating a dogleg, differentialsticking analysis, etc.

Min/Max Tension SimulationForce analysis running in and out for a given well andtoolstring, based on expected well parameters (fluid, friction, deviation, well state, etc.)

Full-Tension Simulation – Historical DataForce analysis using historical data to refine the dragmodel to achieve an optimized tension profile based onactual recorded well tensions.

Full-Tension Simulation – Flowing WellForce analysis in a well with flowing borehole fluidsadded to the basic model to determine the maximum recommended flow rate.

Sensitivity AnalysisHelps identify inherent well or toolstring properties thatmake a planned well intervention particularly sensitive todefined types of risk, i.e. not getting down and insufficientpull capacity.

Pipe Conveyance AnalysisFull analysis of forces in a specific PCL operation todetermine the number of latches required, latching depth(s),weakpoints, optimum wireline-tension profiles, etc.

Tractor Conveyance AnalysisFull analysis of wireline forces required to perform operations with the use of downhole tractors, it allowsdetermining the tractor pull specifications, the interval totractor, optimum tension profile, etc.

Pump Down Conveyance AnalysisThrough full analysis of wireline forces required to per-form a pump down operation, it allows determining theintervention feasibility, ideal piston OD, pump rates andrunning-speed profiles.

Deployment OracleA consultancy service where deployment experts:

Assess the deployment risks present in a planned operation or a set of operationsQuantify success likelihood and associated cost using adecision-tree methodology Provide customers with recommendations on how to bestachieve their well-intervention objectives that supporttheir priorities, i.e. “data assurance,” “minimum cost,” etc.

The surface wireline tension curves in this graphdepict the ability of the system to get in and out of adeviated well while highlighting the possibility ofdamaging the wireline and the impossibility of breakingthe 8,000-lb (3,628.7 kg) weakpoint should the tool-string get stuck below 5,000 ft (1,524 m).

This table depicts the sensitivity of the pulling capacityof the model to the friction coefficient and the wirelinestrength.

This graph depicts the ability to reach the perforatingdepth of three different gun assemblies; the bluecurve shows the effect on the surface tension of thetractor being powered up at ~10,500 ft (3,200 m) topull 300 lb (136 kg).

XSMC – High-Strength Multi-Conductor Cable


High-Strength Wirelines Have Greater Pulling Capacity

Log Deeper with More Sensors


OperationHigh-strength wirelines operate similarly to standard wireline. However, the size and safe working load for thespooling drum and rig-up equipment must be compatiblewith their enhanced specifications.

HighlightsIncrease overpull capacityModern versions are crush-resistant.

BenefitsReduce risk of wireline mechanical and electrical failureEnable wireline conveyance in deeper wellsAllow longer, heavier toolstring combinations per runImprove job efficiency

High-strength wirelines can be operated safely at higherworking loads without electrical or mechanical failure.This means that heavy toolstrings can be deployed indeeper wells while still providing sufficient overpullcapacity.

Example of multi-conductor wireline cross-section illustrating the 7-conductordistribution, insulation, inner and outerarmor wires.

High-strengthwireline mountedon spooling drum

Description Nominal Diameter Breaking Strength Vendor Designation

Extra Strength 0.474 in. 12.04 mm 23,600 lb 10,705 kg 7H47

Ultra-Strength 0.490 in. 12.44 mm 25,200 lb 11,431 kg 7Q49RTZZCrush-Resistant

Ultra-Strength 0.484 in. 12.29 mm 28,200 lb 12,791 kg 7Q48

Specifications – Camesa

Description Nominal Diameter Breaking Strength Vendor Designation

Extra Strength 0.472 in. 11.99 mm 24,500 lb 11,113 kg 7H472

Ultra-Strength 0.490 in. 12.44 mm 26,500 lb 12,020 kg 7H490KCrush-Resistant

Ultra-Strength 0.484 in. 12.29 mm 27,600 lb 12,519 kg 7H484K

Specifications – Rochester

Information for these products is as per publications dated February 2008

PSW – Powered Capstan


Powered Capstans Eliminate High Spooling Tensions

Avoid High Tension Safety Hazards


Operation

The wireline is threaded through the powered capstan’s wheels which maintain the tension onthe unit side at a constant selectable amount, whileallowing downhole tensions to vary from 0 to20,000 lb (9,072 kg).

HighlightsCompact and easily transportableCan be rigged up in horizontal or vertical configurations, as shown in images.Two independent tension meters monitor theunit-side tension and well-side tension.

BenefitsReduces the risk associated with high tensionexerted on the wireline segment between thelogging unit and the rig floorPrevents wireline damage (drum crush) causedby spooling high-tension wireline over low-tension wirelineProvides wireline mechanical and electrical stabilityImproves the consistency of the magnetic marksfor better depth control

Specifications

A powered capstan reduces the risk associatedwith high tension exerted on the wireline segment between the logging unit and the rigfloor. It also prevents wireline damage causedby spooling high-tension wireline over low-tension wireline (drum crush).

Powered Capstan – vertical rig up

Powered Capstan – horizontal rig up


Cable Speed 0 - 300 ft/min 0 - 91 m/min

Cable Tension 0 - 20,000 lb 0 - 9,072 kg

T2

T1

TensionMeter

TensionMeter

TensionReliefDevice

Toolstring

LoggingUnit

Wireline

T1 = constant low tension

T2 range = 0-20,000 lb

EEJ – Hydraulic Wireline Jars ISJ – Mechanical Wireline Jars


Fishing is Costly and Should Always Be Avoided

Preventing Stuck Tools


Operation

Wireline jars are inserted as near as possible to the cablehead.If the toolstring becomes stuck and the pulling tension exceedsa pre-set value, the jars initiate a tensile strike that is deliveredto the stuck point. If the initial strike, which is several timesgreater than the maximum pull achieved, is insufficient thenadditional strikes are delivered to free the toolstring.

Wireline jars should be used when:The maximum overpull at the toolstring is restricted by thewireline’s safe-tension limit.The selected cablehead mechanical weakpoint does not allowsufficient overpull to be exerted to the stuck toolstring.The well’s tortuosity severely reduces the tensions that canbe pulled downhole.The weight of the toolstring makes it more difficult to generate significant pulls on the stuck toolstring.The toolstring is to be maintained stationary for long periodsover permeable reservoir rocks (sampling/testing tools).The well geometry, trajectory, mud properties and field experience suggest that the toolstring is likely to become differentially stuck.The daily rig rate or the cost of deferred production makesthe financial impact of a fishing job unacceptable.

Wireline jars provide a proven and effective means of freeing stuck tools by producing a large impact to the toolstring rather than depending only on wireline pulls.

Jars Firing Sequence, 1. Toolstring logging up, 2. Pulling on a stuck toolstring, 3. Jars fired, 4. Toolstring free, logging continues






Lock Setting 1,800 - 4,000 lb 816 - 1,814 kg

Specifications – Openhole Hydraulic Jars


Length 5.1 - 6.3 ft 1.6 - 1.9 m

Diameter 1.69 - 2.75 in. 43 - 70 mm



Lock Setting 300 - 1,500 lb 136 - 680 kg

Specifications – Cased Hole Hydraulic Jars






Lock Setting 1,000 - 4,500 lb 454 - 2,041 kg

Specifications – Openhole Mechanical Jars


Length 4.5 - 6.0 ft 1.4 - 1.8 m

Diameter 1.56 - 1.81 in. 40 - 46 mm



Lock Setting 300 - 1,800 lb 136 - 816 kg

Specifications – Cased Hole Mechanical Jars

1 2 3 4

RHRA – High-Efficiency FlywheelsRLSC – High-Performance Tool PositioningROLI – Roller Assembly


New Technologies Reduce Drag and Differential Sticking

Get Where You Want to Go Without Getting Stuck


AdvancedConveyance

Device

High-EfficiencyFlywheels

High-PerformanceTool Positioning

Roller Assemblies

Description

A series of clamp-ondevices which use“rolling caps” instead ofwheels to support thetoolstring on their curvedprofile while spinningover low-friction bearings

A clamp-on device thatmaintains the toolstringand sensors azimuthallyoriented, centered, or “stood-off” in the wellbore.

A series of devices thatsupport the weight of the toolstring on large-diameter wheels

Advantages

Minimum contact areareduces differentialstickingLarge-diameter rolling“caps” allow toolstringto ride over debris orwell imperfections withminimum friction.Increases unassistedwireline target depth inhigh-angle wellboresNo wheels

Reduces contact area tominimize differentialstickingImproves response dueto controlled sensorpositioning in the borehole

Reduces contact areato minimize differentialsticking

Lowers friction forimproved wireline overpull capacityIncreases the unassisted wireline target depth in high-angle wellboresAvailable in clamp-onor in-line designs

Disadvantages

Increases toolstringdiameterSensor eccentricitymight, or might not be beneficial

Increased toolstringdiameterSensor eccentricitymight, or might not be beneficial

In-line design increases toolstringlength.Wheels might follow ruts.

Operation

These devices connect in-line or are clamped on at multiplepoints along the toolstring body. Their inclusion reduces thesurface area in contact with the wellbore and friction forcesacting on the toolstring.

Advanced conveyance devices are frequently added to a toolstring to eliminate or mitigate the risks thatjeopardize safe and fast wireline interventions in modern complex wells.

FlywheelTool Positioning Device

Roller Assembly

SWVL – SwivelsKNJ – Knuckle JointsHFD – Hole Finders


New Technologies Improve Conveyance in Tortuous Wells

Getting Where You Want to Go is Not Always Easy


Operation

These devices connect in-line with the body of the toolstringto improve conveyance through borehole ledges, washoutsand high-angle doglegs.

Advanced conveyance devices that allow sufficient toolstring flexibility to navigate tortuous wellbores whileoptimizing pad and sensor orientation.

AdvancedConveyance

Device

Wireline Swivel

Knuckle Joint

Hole Finder

Description

Allows adjoining portions of the toolstringto rotate independently

Allows an angular offset between adjacent instruments

Installed at the bottom ofthe toolstring to reducedrag forces while runningin hole

Advantages

Isolates the toolstringfrom the normal torqueinduced as the spiral-wound wireline is low-ered into and pulled outof the wellMinimizes toolstringrotations that reduce logqualityReduces the risk ofcable damage

Optimizes wellboresensor positioning whenneighboring sensorsrequire varying degreesof standoffReduces toolstring dragfriction when traversingwellbores with highdogleg severity

Improves toolstringmovement throughobstacles such asledges, debris and sections of high dogleg severity

Disadvantages

In-line design increases toolstring length.

In-line design increasestoolstring lengthReduces tensile andcompressive strength

Some devices mightincrease toolstringdiameter.Increases toolstring length

High-PerformanceHole Finder

Double Knuckle Joint Wireline Swivel

Contingency Services and Devices


Services and Equipment to Deal with Unexpected Hazardous Conditions

Essentials for When Well Interventions Go Wrong


Primary Application

Unable to reach target depth Sticky conditions and/or servicesPoor hole geometry/trajectoryHigher tensions than expectedInsufficient downhole pull capacityLoss of well control

The first five contingency services/equipment included in this table are covered in the following pages; the other seven are documented in the previous pages of this section - Deployment Risk Management.

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One of the critical tasks of a well intervention planning process, often neglected, is the selection and provisionof services and equipment required to recover from conditions resulting from unplanned events.

The following is a list of the most common situations that require contingency planning ahead of time:Unable to reach the target depthStuck toolHigher wireline tensions than anticipatedHigher friction coefficient than anticipatedNot enough downhole pull capacityEvidence of differential sticking conditionsHigher-than-expected overbalance pressuresUnexpected high-dogleg severityLoss of mud circulationLargely washed-out sectionsSignificant cuttings or debris in deviated wells

The more remote and isolated the wellsite is from major oil and gas support locations, the more importantbecomes the need to have contingency equipment/services readily available onsite to avoid costly incompleteoperations, wasting of expensive rig time and the financial loss resulting from the deferred production of all thewells planned with the drilling rig.

Alternative conveyance systems, pipe conveyed logging and downhole tractors in particular, are frequentlymobilized for jobs where the risk of not getting down to the target depth with unassisted wireline is unacceptable.These interventions are first attempted with wireline alone, and operators will switch to pipe or tractor conveyanceonly if the toolstring cannot reach the target depth.



Using Drillpipe and Wireline to Free Stuck Tools and Finish the Logging Job

Completing a Job While Recovering a Stuck Toolstring


LWR – Logging While Retrieving

OperationThe LWR operation starts when the wireline is threadedfrom the inside to the outside of the pipe using a side-entry sub inserted on top of a drillpipe stand duringa cut-and-thread fishing operation.The loose ends of the wireline are then spliced using adouble-ended torpedo to recover its mechanical and electrical integrity.The drillpipe is then run in hole until the grapple, part ofthe fishing assembly, latches on the stuck toolstring, andthe drillpipe is worked until the tollstring is free.The logging operation is then resumed in the required direction by moving the wireline and the drillpipe synchronously.After the logging operation is completed and the side-entry sub is back at the surface, the wireline is pulled out of the toolstring cablehead and retrieved priorrigging down the side-entry sub and wireline to extractthe toolstring.

HighlightsIntended for cut-and-thread fishing operationsEffective in key-seated wireline, a stuck tool or whenboth conditions existEqually applicable for stationary or moving logging servicesNot recommended when the loss of well control is alikely event; the presence of the wireline outside thedrillpipe will not allow achieving an effective seal in an emergency.To provide an effective means of removing the wirelinefrom the well, a Hydraulic Wireline Severing Tool shouldbe inserted in the drillpipe fishing downhole assembly.Requires experience personnel and careful planning

BenefitsReduces the rig time required to fish the stuck toolstringand log the target intervals in an additional run Eliminates the need of a conditioning tripReduces the number of threading events and the associated safety hazardsAllows the use of strong weakpoints to increase thedownhole pulling capacity that helps prevent toolstrings from getting stuck

The use of the Logging While Retrieving (LWR) servicereduces the overall cost of a fishing operation by allowing the completion of the logging run while recovering a stuck toolstring.

The loose ends of the wireline, cut during a cut-and-thread fishing operation, are spliced usinga torpedo outside the side-entry sub to allow the logging operation to resume after the stuck toolstring is latched and worked free.

In addition to the side-entry sub, a high-strengthtorpedo and dual-groove sheave wheels, shown inthis photograph, are part of the LWR kit.

MRCH – Multi-Conductor Releasable Cablehead


Electrical Wireline Release Built in the Cablehead

Log Heavy Toolstrings While Avoiding a Fishing Job


Operation

The MRCH includes a latching assembly that, in a stuck-tool situation, can be electrically activated to disconnect thewireline from the toolstring to allow its fast extraction fromthe well.

HighlightsIncludes safeguards to prevent unintentional activationCan host a back-up “tensile bar” weakpoint should thewireline lose electrical integrity while trying to work thestuck toolstring free

BenefitsEliminates the need to pull high tensions to disconnectthe wireline from a stuck toolstringEliminates the need for mechanical weakpoints, whichmeans that:• Heavy toolstrings can be deployed. • Deep and/or deviated wells can be logged in fewer runs.• Higher tension can be pulled on toolstrings that help

prevent them getting stuck.

Specifications

The Multi-Conductor Releasable Cablehead allowsremoving the wireline from the well in a stuck-tool situation without pulling high tensions. The MRCH alsoreduces the rig time and cost in well conditions conducive to stuck toolstrings.

Wireline Release Sequence1. Toolstring logging up, 2. Pulling does not freethe toolstring, 3. Release mechanism is activated.


Length 75.3 in. 1.91 m

Diameter 3 3⁄8 in. 85.8 mm





Electrical Wireline Release Built in the Toolstring

Log Heavy Toolstrings While Avoiding a Fishing Job


ART – Single-Conductor Releasable Tool

These sequences depict how two releasable tools inserted in a toolstring can be activated individually to release the free part of a stuck toolstring.

Operation

This type of releasable tools are often inserted immediatelybelow the cablehead and between the top correlation/conveyance section and the bottom passenger tool/gun section.

Depending upon which part of the toolstring is stuck, thetop or bottom releasable tool is activated to allow pullingthe wireline and free tools out of the well while leaving a fishing neck profile looking up on the stuck-tool section.

HighlightsIncludes safeguards to prevent unintentional activationOften used in perforating and downhole tractor interventions

BenefitsAllows a controlled retrieval of the wireline and free toolspart of a stuck toolstringReduces rig time, cost and the risks associated with stucktools and complex fishing operations in live wells

Specifications

Releasable tools allow the safe removal of the wirelineand the tools above the stuck-tool section, eliminatingthe need to build a mechanical weakpoint in the cablehead.

Description ART-C ART-F ART-T

Diameter 111⁄16 in. 2 1⁄8 in. 2 1⁄8 in. 43 mm 54 mm 54 mm

Pressure Rating 15,000 psi 15,000 psi 20,000 psi103.4 MPa 103.4 MPa 137.9 MPa

Temperature 350º F 350º F 400º F 177º C 177º C 204º C

Remarks Approved for Notballistic operations addressable

HWST – Hydraulic Wireline Severing Tool


Devices to Cut the Wireline Under Tension at Surface or Downhole

Cutting the Wireline Quickly and Safely


Surface wireline cutters include a hydraulic cutting assemblymounted around the wireline section going in the well above the rigfloor level and a control hydraulic pump connected through a hose tothe cutting assembly.

To cut the wireline, the operator uses the control pump, while in aprotected area, to increase the pressure on the cutting assembly untilthe wireline is severed.

The RWCC cutters include a hydraulic wireline clamp that grips onthe upper part of the wireline before the cut takes place to avoid thedangerous wireline recoil.

Surface wireline cutters provide a fast and safe method to clearthe wireline from the surface well control tree when there is notenough time to remove the wireline from the well.

RWCC and RWC – Surface Wireline Cutters

OperationThe HWST is inserted in the drillpipe fishing downhole assemblyabove the overshot.After the stuck toolstring has been secured inside the overshot, theHWST can be activated by pumping above a pre-defined rate.After a set of screws, holding the top piston in place, shear, the piston rushes down to impact a ramp profile that drives a sharpblade laterally to cut the wireline.The wireline is then removed quickly from the well to allowretrieval of the drillpipe toolstring.

HighlightsOnly required/used after making the decision to fish the stuck toolwith drillpipeDoes not rely on the integrity of the electric conductor’s portion ofthe wirelineA Baker Hughes proprietary design and the only one of its kindcurrently offered

BenefitsAllows a controlled retrieval of the wireline after the stuck tool-string has been secured inside the fishing assemblyReduces rig time, cost and the risks associated with high tensionsrequired to break mechanical weakpointsProvides back up for interventions planned with electricalreleasable cableheadsWhen used in logging while retrieving operations, it provides aneffective means to remove the wireline from the well if loss-of-control conditions develop.

The Hydraulic Wireline Severing Tool provides a safe method to remove the wireline after catching the stuck toolstring in astrip-over fishing operation. The HWST allows the performanceof logging operations without the use of mechanical weakpointsor releasable cableheads.

This schematic shows the wireline goingthrough the HWST inserted immediatelyabove the overshot fishing assembly wherethe toolstring cablehead is securely held.

WIRELINECUTTINGBLADE


Length 27.5 in. (699 mm)

Diameter 5.75 in. (146 mm)

Max. BHT 450º F (232º C)

Max. BHP 30,000 psi (207 MPa)

Specifications

Nautilus

8. Hostile Environment Services

VIII

Nautilus – Extreme High Pressure/High Temperature Logging Instruments

Baker Atlas8-2 Hostile Environment Services: Nautilus Services Catalog Version 2.1; August 2008

Operation

Nautilus Hostile instrumentation is available for conditionsup to 500° F (260° C) and up to 30,000 psi (206 MPa). Theservice range features the latest technologies including com-plete formation evaluation, formation testing and sampling.In addition, borehole seismic, production logging and piperecovery services complement the service range.

Nautilus delivers high-pressure, high-temperature reliabilityand performance, coupled with the measurement integrityand accuracy already delivered by our standard range ofinstrumentation. To qualify for the NAUTILUS signature,instruments must be rated above 400° F (204° C) and/or20,000 psi (137.9 MPa). To determine if Nautilus HP, HT orHPHT instrumentation will meet the challenge of your nextextreme hostile well, speak to a Baker Atlas representative.

When planning an HP, HT or HPHT logging operation, thefollowing factors should be considered. Hostile wells aretypically characterized either by a high temperature or ahigh pressure component. There is a relationship between the performance of instruments at temperature and pressure.Time in the well and time the instrument is powered are both key factors in the capability of the instrumentation to perform in hostile conditions. Therefore, conveyancemethods and strategy is a key element of hostile instrumentperformance. The performance of the instrument will vary,dependent on the maximum pressure, the temperature actually reached and the time deployed in the well (bothpowered and un-powered). Any published specifications are intended as a guide only and performance for specific wellconditions must be modeled and verified with a Baker Atlasrepresentative.

ServicesFormation evaluation Formation testing and sampling Borehole seismic Production logging Cement evaluation

Nautilus is Baker Atlas’ range of high pressure and hightemperature logging instruments, designed for perform-ance and reliability in the most extreme conditions. Newexploration horizons are extending the limits of boreholedepths. As these limits are extended, the pressures andtemperatures encountered become more challenging.

Log in Temperatures and Pressures Up to 500º F (260º C) and 30,000 psi (206 MPa)

High Pressure/High Temperature

WellLink

9. Data Delivery/Management Services

IX

Baker Atlas

WellLink – Data Delivery Service

Baker Atlas9-2 Data Delivery/Management Services: WellLink Services Catalog Version 2.1; August 2008

Operation

With a standard web browser, Internet access and a loginaccount to the e-business portal www.bakerhughesdirect.com,clients can access real-time and archived data. Well-data eventsare announced via email and text messaging to cell phones orpagers. 24-hour support centers assist clients and continuallymonitor all systems hosted in a best-in-class offsite environment.Static files uploaded from any data provider are automaticallyloaded to WellLink Data Services allowing entitled clients todownload data in their preferred formats immediately and foryears thereafter. Distribution tools further support Blitz, Fax,Email and FTP to multiple global destinations. The LiveWireService supports viewing, interpreting and accessing real-timeWireline data with results downloadable from WellLink DataServices. With LiveDecision, you literally have your own work-station at your fingertips. The RigLink Service hosts any real-timeWITS or WITSML data from surface and LWD sensors. User-configurable displays, measurement units and threshold alarmsenhance usability and time-critical decisions while drilling.

HighlightsReal-time wireline (ECLIPSSM system)Applications to interpret data“Turnkey” for all electronic well data delivery and managementDesktop delivery regardless of file sizePlatform independent web-browser accessAudit trail of all activity and distributionsClient administration and reporting availableCustomizable user profile settings in all systemsSingle login for all well data and service informationComprehensive long-term archive for all wellbore data Easy integration into 3rd party applicationsAccess to Baker Hughes experts and 24/7 tech support

BenefitsManage risk by making confident and timely decisionsthrough simultaneous multi-user collaboration Reduce personnel requirements at the wellsite to simplifylogistics and reduce HSE exposure Keep your experts in the office for higher productivityImmediate decisions on downhole fluid sample qualityOnline access – anywhere, anytime – in your format

LiveWire – Real-Time Decisions during Wirelinedata Acquisition or Fluid Sampling

RigLink – Real-Time Decisions while Drilling

Secure desktop access to live and archived wells

The WellLinkSM service is the Baker Hughes web-baseddata delivery service. It provides information sharing andease of decision-making throughout the life of a well. TheWellLink service provides a more efficient work environmentto make business decisions that impact profitability andreduce risk. With the leading distribution system to securelymove information to well stakeholders, the user-friendlyWellLink service is flexible and intuitive. The WellLinkservice, through the LiveWire, LiveDecision and RigLinkapplications, also facilitates real-time collaboration anywhereand anytime needed to save both time and money.

Data Delivery – Data Management

Desktop Access to Real-Time and Archived Well Data

Acoustic Waveform AnalysisGeomechanics ServicesNuclear Magnetic Resonance Analysis Resistivity ProcessingDiplog AnalysisBorehole Image AnalysisCased Hole AnalysisProduction Log AnalysisPipe Evaluation

10. Geoscience Services

X

Acoustic Waveform Analysis

Baker Atlas10-2 Geoscience Services

Advanced Acoustic Waveform Processing and Interpretation

Geoscience


Service Description

Acoustic waveform energy analysis is provided to compute the amplitude and attenuation of compressional,shear or Stoneley wave types to identify fractured forma-tion intervals and as a qualitative formation permeabilityindicator. Other acoustic interpretation products areavailable for determination of the magnitude and orien-tation of azimuthal and transverse formation anisotropy.Results of acoustic waveform data analysis can be integrated with borehole image and caliper logs for anin-situ stress regime and borehole stability analysis.

Acoustic Waveform ProcessingSlowness processing (compressional/shear/Stoneley)High-resolution slowness processing (compressional)Waveform energy analysis

Acoustic Waveform InterpretationAnisotropy analysis – azimuthal/transversePermeability indicator (Stoneley)Calibrated permeabilityFracture evaluationFluid identification (ALHI – Acoustic Log Hydrocarbon Indicator)

Service ApplicationCompressional, shear and Stoneley velocity measurements determination Enhanced vertical resolution of acoustic velocities Acoustic anisotropy and formation geomechanics

BenefitsAccurate measurement of fast and slow shear slowness allows determination of the magnitude and direction of anisotropy for stress determinationand fracture identificationPorosity determination and permeability estimation

Acoustic waveform data processing offers a completesuite of products that provide an accurate determi-nation of compressional, shear or Stoneley wavevelocity measurements. Openhole and through-casinganalyses are both possible. Acoustic waveforminterpretation products are available for fractureidentification and orientation and fluid identification.

XX100XX200

XX300XX400

XX500

Geomechanics Services

Baker Atlas 10-3Geoscience Services

Mechanical Properties Determinations

Geoscience


Service Description

Geomechanical products use highly complex deterministic models to estimate formation mechanical properties, in-situ stresses and pore pressure. The basic dynamic properties product provides a continuous profile of elastic constantssuch as Young’s modulus, Poisson’s ratio, bulk modulus, and compressibility. These parameters arederived from acoustic and density data and are theprerequisites for any geomechanical study. A uniqueadvanced product available only from Baker Atlas,LMP (Logging Mechanical Properties), allows youto compute static mechanical properties and rockstrength directly from log data. Geomechanical earthmodels are integrated with operational data fromdrilling, completion, stimulation and production.These integrations provide the most comprehensiveand realistic geomechanical solutions for wellboreconstruction and reservoir exploitation.

Basic Geomechanics ServicesDynamic mechanical propertiesFracture migration prediction (vertical holes only)Sand production analysis (vertical holes only)Openhole stability prediction (vertical holes only)

Advanced Geomechanics ServicesStatic mechanical properties and strength (LMP)Bulk and pore volume compressibilities In-situ stress tensor analysis Pore pressure prediction Borehole stability analysis Critical drawdown pressure (sand production) prediction Casing integrity analysis Critical stressed fractures and fault analysis

Service ApplicationMud weight window profiles at specific breakoutsizes; Contour plots delineating stable wellboretrajectoriesFracture gradient and pore pressure profilesCritical drawdown pressure profiles for sand control considerations including selective and oriented perforations

Geomechanics deals with the deformation andfailure of rocks under downhole stresses.Whether drilling and/or completing a well, BakerAtlas offers a complete suite of geomechanicalproducts that provide accurate solutions for optimizing drilling and completion programs.

XX100XX200

Casing collapse prediction and mitigation Wellbore placement in naturally fracturedformations to enhance production

BenefitsReduced drilling and completion costs Enhances reservoir production

Nuclear Magnetic Resonance Analysis


Analyzing Reservoir Fluids with NMR Data

Geoscience


Service Description

MREX data analysis products are available for the fullrange of applications. New technology has enabled analysisof the MREX data to produce 2-D-NMR images for fluididentification and quantification. The petrophysical analysisservice integrates the MREX data with conventional datato provide a more comprehensive and accurate volumetricanalysis. Reservoir engineering applications include in-situviscosity determination, permeability and productivityanalysis. Integration with core data enables accurate reservoir characterization for permeability and irreduciblewater saturation.

Service Applications

Formation evaluation

Saturation determination

Porosity determination

NMR-based permeability

Hydrocarbon identification and quantification

• Distinguish gas, oil and water and identify contacts

• Identify hydrocarbons in low-resistivity zones

• Shaly sand evaluation

• Identify non productive hydrocarbons – heavy oil andtar mats

• Quantify hydrocarbon volume in place

Benefits

Accurate formation evaluation and characterization

Direct identification and quantification of hydrocarbons

Reduced uncertainty in reserves estimates

Improved surface handling facilities design inputs

Nuclear Magnetic Resonance (NMR) data processingservices include the complete range of products toprocess MREX data for signal-to-noise enhancement,vertical resolution enhancement, T1 and T2 cutoffadjustment reprocessing and borehole signal correction processing.

D vs. T2,int 2-D NMR image, crossplot of D spectrum and T2,int spectrum

e-8

e-9

e-10

e-112 8 32 128 512 2048

T2,int (ms)

D (

m2/s

)

Water line

Water response

Oil response

Oil line

T1/ T2,app versus T2,app 2-D plot, differentiation of fluids

2 32 512

T2,app (ms)

16

4

1

BVI

GAS

OBMF

T1/T

2,a

pp

CBW

Baker Atlas 10-5Geoscience ServicesServices Catalog Version 2.1; August 2008

Processing and Interpretation of Resisitivity Data

Resistivity Processing

Geoscience

Service Description

The 3D Explorer Induction (3DEX EliteSM) service,which measures the resistivity tensor in both the horizontal and vertical directions, was developed toprovide improved identification and quantification ofhydrocarbon saturations in thin-bedded or laminatedsand-shale sequences. 3DEX Elite tensor petrophysicalanalysis provides for accurate hydrocarbon volumedetermination. The 3DEX Elite resistivity responsesalso allow accurate dip and azimuth determination evenin an oil-based mud environment.

Resistivity Data ProcessingHigh-resolution processing for array services – In homogeneous backgroundFocusing for HDIL1-D Inversion processing2-D Fast Inversion – HDIL onlyHorizontal well near/far zone – HDIL only

3DEX Data Processing and InterpretationPrejob modeling Deviation processing – Dip/AZResistivity processing – Rh, Rv

Service Application Formation resistivity profile determination 1-D, 2-D, or full 3-D forward modeling in horizontalwells or wells with complex resistivity distributions Thin-bed environment, low-resistivity pay evaluation Accurate dip and azimuth determinationFracture identification

BenefitsImproved hydrocarbon in-place determination

A complete suite of products is available to providethe most accurate determination of formation resistivity possible for all the Baker Atlas resistivitydevices. 1-D and 2-D inversion processing is available to obtain a reliable resistivity profile aswell as horizontal well near/far zone interpretation.Enhanced resolution processing with adaptiveborehole and accelerometer (cable speed) corrections is also available.

XX200

Baker Atlas10-6 Geoscience Services Services Catalog Version 2.1; August 2008

Processing and Interpretation of Diplog Data

Diplog Analysis

Geoscience

Service Description

The Diplog traces can be displayed aspseudo-resistivity images for an enhancedinterpretation. The traces may also be calibrated with a shallow-focused resistivitycurve (M1R1 or RFOC) to generate a high-resolution resistivity curve (Rxo) that can beused for thin-bed formation evaluation. Thedirectional survey provides a graphic projectionof the well using borehole inclination andazimuth measurements. The borehole profileand cross-section can be generated usingeither 4- or 6-arm oriented caliper data.

Basic Diplog Processing andInterpretation

Automated dip computationManual (interactive) dip computationGeneration of resistivity images fromdiplog curvesDirectional surveyBorehole profile

Advanced Diplog Processing andInterpretation

Structural interpretation Borehole breakout analysis from caliper dataNet-to-gross analysis

Service ApplicationDetailed structural interpretation when usedwith seismic dataThin-bed evaluation

BenefitsImproved exploration and production resultsCost-effective method for verificationand/or enhancement of seismically derived structural model

Processing and interpretation of DiplogSM

data offers a complete suite of computedinterpretation products for dip magnitudesand azimuths of bed, fracture planes and other structural features. Diplogs can be processed automatically or interactively for detailed structural andsedimentological analysis.

Image is representative of log

XX00XX00

Borehole Image Analysis


Processing and Interpretation of Borehole Images

Geoscience


Service Description

Different filters are applied to enhance image quality andaccuracy prior to interpretation. Manual (interactive) dipcomputations provide for accurate geological feature identi-fication. Structural features such as bedding, fractures,drilling-induced fractures, borehole breakouts, sedimentarybedding, etc. can also be easily picked. Cross-sections and 3-D borehole profiles may be generated using two-waytravel time from pre-processed acoustic image data or 6-armoriented caliper data from a resistivity borehole imaging tool.

Advanced borehole imaging products allow for detailed structural interpretation and identification of basic structuralfeatures such as formation tops, faults and unconformities.Results of borehole image structural analyses can be integrated with seismic data to verify or enhance an existingstructural model. Detailed fracture interpretation includesdescription of the dip and strike of fracture sets, apparentlength, spacing and statistical results. A semi-quantitativecalculation of fracture aperture and porosity estimation isalso available. Borehole image sedimentological interpreta-tion from acoustic and/or resistivity images is used to identify sedimentary facies or lithofacies. Image log inter-pretation can be integrated with additional wireline log orcore information for advanced reservoir description.

Basic Borehole Image Data Processing andInterpretation

Single and dual image processingManual dip computation from imagesGeneration of synthetic Diplog curvesHigh-resolution resistivity curve (Rxo)

Advanced Borehole Image Data Processing and Interpretation

Formation evaluation and pro-ductivity analysis via integrationof NMR and conventional logsStructural/sedimentologicalinterpretationBorehole breakout analysisFracture system characterizationNet-to-gross analysisPaleotransport and faciesanalysisCore integration

Whether you are dealing with clastic or carbonate reservoirs, highly complex structural settings, naturalfractured reservoir or requiring detailed sedimentologicalinterpretation, Baker Atlas' imaging analysis serviceoffers a complete suite of products that provide accurateprocessing and interpretation of borehole image data.

Service Application Borehole image processing and interpretationprovides accurate structural interpretationwhen used in conjunction with seismic dataDescription of fracture type, orientation, connectivity, aperture and estimate of fracture porosityThin-bed evaluation Analysis of sedimentary bedding features,facies, lithofacies and sediment transportinferences

Benefits Identification ofreservoir structuraland sedimentologi-cal featuresReduced coring andassociated drillingcosts (partial corereplacement)

Image is representative of log

Cased Hole Analysis


Cased Hole Formation Evaluation

Geoscience


Cased Hole Formation EvaluationPNC Sigma Sw interpretation (2-phase)C/O Sw interpretation (oil/water)PNC-3D GasView Sg interpretationPNC-3D Pressure depletion detectionAdvanced PNC Sigma and GasView 3-phase saturationanalysisAdvanced C/O and GasView 3-phase saturation analysis

Special ProgramsLog-Inject-Log analysis Time-Lapse Monitoring Emulation of openhole logs

Service ApplicationCased hole formation and saturation evaluationGas saturation analysisFormation evaluation in presence of tubing stringsTime lapsed fluid monitoringEnhanced oil recovery project monitoring

BenefitsReservoir monitoring and management Bypassed hydrocarbon exploration in abandoned orworkover wellsNew well evaluation when openhole logs are not available

The Reservoir Performance Monitor (RPM) instrumenthas several operational modes for formation evaluationand saturation analysis. In Pulsed Neutron Capture(PNC) mode the time spectra from short-spaced andlong spaced detectors are processed to provide traditionalthermal neutron capture cross sectional information tocompute water saturation in reservoirs with saline formation water. The Carbon/Oxygen (C/O) mode utilizesinelastic gamma ray spectroscopy measurements tocompute water saturation in reservoirs that contain fresh,mixed, or unknown water salinity water (e.g. water floodprograms). GasView is a salinity-independent methodthat utilizes the PNC-3D mode which incorporates theinnovative 3rd detector in the RPM-C tool to provideimproved gas detection and saturation measurements.

Formation water saturation analysis can be performed using PNC Sigma or Carbon/Oxygenmeasurements (C/O analysis shown).

The unique interpretation product GasViewSM

provides a new method to quantify formation gassaturation where conventional pulsed neutron interpretation methods are ineffective, and canalso be used to identify pressure-depleted zones.

Dynamic Gas Envelope LMS

Gas Indication Gas

Gas Flag Fluid

150 Gas Curve 01 Gas Saturation 00 12000

Wet sideof DGE

Gas sideof DGE

Measured curveused for gas

analysis

GAS—Curve departure from the wet side of the DGE indicates the presence of gas,

and the degree of departure indicates the gas saturation.

WET—The measured curve moving along the wet side of the envelope indicates

the absence of gas.

The correspondence of the measured curveand the DGE water line in wet zones is an

indicator of the integrity of the interpretation and the validity of the porosity, shale,

and cementation volumetrics.

Production Log Analysis


Production Logging and POLARIS Analysis

Geoscience


Production Log AnalysisSingle-phase flow profile2-phase flow profile3-phase flow profile2-phase POLARIS analysis3-phase POLARIS analysisHydrologAnnular Flow LogPulsed Neutron Holdup Imager – 2-phase or 3-phasePRISM multi-tracer injection analysis

Service ApplicationDetermine multiphase production profiles in vertical to horizontal wellsIdentify water entry points and accurately determine injection profilesIdentify waterflow behind casingDetermine borehole fluid holdup and distributionMonitoring multiple tracer distribution for measuring effectiveness of hydraulic fracturingand well stimulation

BenefitsValuable analyses for use in formation and reservoir performance evaluation, monitoringand managementBorehole diagnostics, identifies casing leaks,water channeling, other behind pipe waterflowfor planning repair and remediation work

The production log services improves ourunderstanding of wellbore fluid flow in a widerange of complex reservoir conditions in adynamic production environment. The POLARISservice, a multisensor multifunction system,provides a comprehensive range of acquisitionmodes in a single logging string for highly-deviated and horizontal wells, and the efficientPRAL system is used for production logging invertical and deviated wells. The analysis of theacquired data provides a clear understandingof the reservoir performance.

Pipe Evaluation


Interpretation of Pipe Evaluation Data

Geoscience


Pipe EvaluationPipe evaluation using flux leakagePipe evaluation using continuous potential profile dataPipe evaluation using acoustic imagingPipe evaluation using EM induction (Magnelog service)Pipe evaluation interpretation report

Service ApplicationComprehensive suite of inspection techniques to measure casing and tubing integrity such asinterior and exterior corrosion, monitoring, interior wear, parting, splits and casing/tubingdeformation Measure the minimum and maximum internaltubing or casing diametersIdentifies casing joints with different weight or wall thickness Confirm locations of leaks and perforationsAssess potential for future continued corrosion

BenefitsEvaluate location and extent of casing and tubing damageDetermines need for casing patches and tubing replacement to ensure well integrityOn-site data analysis provides fast and accurateresults that reduces workover decision time andminimizes lost production

Pipe evaluation services provide fast andaccurate analysis of tubular goods, identifyingdownhole conditions that can compromisesafety and interrupt production. Inspection ofthe production tubing and casing on a regularbasis can provide early detection of problemareas and allow for timely planning of remedial action.

By CategoryAlphabeticalIndex

11. Service Name and Mnemonic Lists

XI

Baker Atlas11-2 Service Name and Mnemonic Lists: By Category

By Category

Service Name and Mnemonic Lists


Service Category Name Service Mnemomic

Resistivity LoggingHigh-Definition Induction Log HDIL

Dual Laterolog DLL

3D Explorer Induction Logging Service 3DEX Elite

Micro Laterolog MLL

Minilog ML

Nuclear LoggingCompensated Z-Densilog ZDL

Compensated Neutron CN

Gamma Ray Log GR

Digital Spectralog DSL

Acoustic LoggingCross-Multipole Array Acoustilog F1 XMAC F1

Digital Acoustilog DAL

Magnetic Resonance ImagingMR Explorer MREX

High-Efficiency LoggingFOCUS High-Definition Induction Log F_HDIL

FOCUS Digital Acoustilog F_DAL

FOCUS Compensated Z-Densilog F_ZDL

FOCUS Compensated Neutron F_CN

FOCUS Gamma Ray Log F_GR

Geological ServicesWater-Based Mud Formation Resistivity Imager STAR

Oil-Based Mud Resistivity Formation Imager EARTH

Circumferential Borehole Imaging Log CBIL

Hexagonal Diplog HDIP

Caliper ServicesWell Geometry Instrument WGI

Pressure Testing/Fluid Characterization and SamplingReservoir Characterization Instrument RCI

Coring ServicesRotary Sidewall Coring Tool RCOR

Sidewall Corgun SWC

Baker Atlas 11-3Service Name and Mnemonic Lists: By CategoryServices Catalog Version 2.1; August 2008

By Category



Borehole Seismic ApplicationsVelocity Survey

Zero Offset Vertical Seismic Profile ZVSP

2-Dimensional VSP 2-D VSP

3-Dimensional VSP 3-D VSP

Hydraulic-Fracture Monitoring

Downhole Seismic ServicesDownhole Receiver Array Geochain GCN

Digital Multi-level Downhole Seismic Array GWV

Multi-Level Slimhole Receiver MSR

PipeSeis PSR

Buried Gun Array

Seismic Logging Systems SLS

Integrated Borehole Seismic Navigation System TASMAN

Energy Sources and Energy Source Controllers

VS Fusion Borehole Seismic Processing2-D Imaging

3-D Migration; 3-C, 4-C Processing

3-D VSP Processing, Interpretation and Integration

Q-Compensating Surface Seismic Data

Special Processing

Post-Survey Modeling

2-D and 3-D VSP Inversion

Presurvey Modeling

Cased Hole Formation EvaluationReservoir Performance Monitor RPM

PDK-100 PDK

Production LoggingProduction Optimization Log and Reservoir Information Solutions POLARIS

Production Logging Services PRAL

Continuous Spinner Flowmeter FMCS

Folding Impeller Flowmeter FMFI

Basket Flowmeter FMBK

Nuclear Fluid Density FDN

Water Holdup Indicator WHI

Nuclear Flolog NFL

Tracerlog TRL

Pulsed Neutron Holdup Imager PNHI

Hydrolog HYDL

Baker Atlas11-4 Service Name and Mnemonic Lists: By Category

By Category




Surface Readout Pressure Gauge SRPG

Noise (Sonan) Log SON

Temperature Log TEMP

Pipe EvaluationVertilog Service VRT

Digital Magnelog Service DMAG

Imaging Caliper Log ICL

Cement EvaluationSegmented Bond Tool SBT

Radial Analysis Bond Log RAL

Acoustic Cement Bond Log CBL

Pipe RecoveryPipe Recovery Log PRL

Free Point Indicator FPI

Spring Anchor Free Point Indicator SAFP

Magna-Tector Free Point Indicator MAFP

String Shot Backoff BO

Chemical Cutter CC

Jet Cutter JCS

Noise (Sonan)/Temperature Log SON/TEMP

PerforatingPerforating Charges Overview

Dynamic Underbalance Optimization Process DUO

Propellant Assisted Perforating Products StimGun

eXtreme Low Debris Perforating Systems XLD

Low Debris Perforating Systems PERFFORM

2” and 2 1⁄2“ Predator Low Swell Guns XPLS

Horizontal Oriented Perforating System HOPS

Snapshot CT Live Well Deployment System

Stackable Gun System SGS

Inter-Gun Automatic Release IGAR

Model J-Gun Brake J-GB

Electro-Magnetic Orienting Perforating EMO

Coiled Tubing Conveyed Perforating CTCP

One-Trip Perforate and Completion Systems NeoTrip

Perforate and Gravel Pack Completion System PDP

TCP Azimuthally Oriented Perforating TCP-AOP

Parallel Perforating System PSI

Tubing-Conveyed Dual String Perforating System

Guardian II/EBW Perforating Package GDN

By Category


Baker Atlas 11-5Service Name and Mnemonic Lists: By CategoryServices Catalog Version 2.1; August 2008


Wireline Conveyance SystemsPipe Conveyed Logging PCL

Tractor Conveyed Logging WTCL

Coiled Tubing Conveyed Logging CTCW

Pump Down Conveyance TDP

Risk-Reduction TechnologiesWell Intervention Modeling Services CERB

Hydraulic Wireline Jars EEJ

Mechanical Wireline Jars ISJ

Powered Capstan PSW

High-Strength – Multi-Conductor Cable XSMC

High-Efficiency Flywheels RHRA

High-Performance Tool Positioning RLSC

Roller Assembly ROLI

Swivels SWVL

Knuckle Joints KNJ

Hole Finders HFD

Logging While Retrieving LWR

Multi-Conductor Releasable Cablehead MRCH

Single-Conductor Releasable Tool ART

Hydraulic Wireline Severing Tool HWST

Surface Remote Hydraulic Wireline Clamp and Cutter RWCC

Surface Remote Hydraulic Wireline Cutter RWC

Hostile Environment ServicesExtreme HPHT Logging Instruments Nautilus

Data Delivery – Data Management ServicesData Delivery Service WellLink

Geoscience ServicesAcoustic Wavefrom Analysis

Geomechanics Services

Nuclear Magnetic Resonance Analysis

Resistivity Processing

Diplog Analysis

Borehole Image Analysis

Cased Hole Analysis

Production Log Analysis

Pipe Evaluation

Baker Atlas11-6 Service Name and Mnemonic Lists: Alphabetical Services Catalog Version 2.1; August 2008

Alphabetical


2-D VSP 2-Dimensional VSP . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-63-D VSP 3-Dimensional VSP . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-5 3DEX Elite 3D Explorer Induction Logging Service . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-5ART Single-Conductor Releasable Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-17BO String Shot Backoff . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-11

Buried Gun Array . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-12CBIL Circumferential Borehole Imaging Log . . . . . . . . . . . . . . . . . . . . . . . . . . 1-27CBL Acoustic Cement Bond Log . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-5CC Chemical Cutter . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-12CERB Well Intervention Modeling Services . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-7 CN Compensated Neutron . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-10CTCP Coiled Tubing Conveyed Perforating . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-15CTCW Coiled Tubing Conveyed Logging . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-5DAL Digital Acoustilog . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-15DLL Dual Laterolog . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-4DMAG Digital Magnelog Service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-21DSL Digital Spectralog . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-12DUO Dynamic Underbalance Optimization Process . . . . . . . . . . . . . . . . . . . . 6-4EARTH Oil-Based Mud Formation Resistivity Imager . . . . . . . . . . . . . . . . . . . . . 1-26EEJ Hydraulic Wireline Jars . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-11EMO Electro-Magnetic Orienting Perforating . . . . . . . . . . . . . . . . . . . . . . . . . 6-14FDN Nuclear Fluid Density . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-11FMBK Basket Flowmeter . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-10FMCS Continuous Spinner Flowmeter . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-8FMFI Folding Impeller Flowmeter . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-9F_CN FOCUS Compensated Neutron . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-22F_DAL FOCUS Digital Acoustilog . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-20F_GR FOCUS Gamma Ray Log . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-23F_HDIL FOCUS High-Definition Induction Log . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-19F_ZDL FOCUS Z-Densilog . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-21FPI Free Point Indicator . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-8GCN Downhole Receiver Array Geochain . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-8GDN Guardian II System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-21GR Gamma Ray Log . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-11GWV Digital Multi-Level Downhole Seismic Array . . . . . . . . . . . . . . . . . . . . . .3-9 HDIL High-Definition Induction Log . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-3HDIP Hexagonal Diplog . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-28HFD Hole Finders . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-13HOPS Horizontal Oriented Perforating System . . . . . . . . . . . . . . . . . . . . . . . . . . 6-9HWST Hydraulic Wireline Severing Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-18HYDL Hydrolog . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-15ICL Imaging Caliper Log . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-22IGAR Inter-Gun Automatic Release . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-12ISJ Mechanical Wireline Jars . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-11JCS Jet Cutter . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-13J-GB Model J-Gun Brake . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-13KNJ Knuckle Joints . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-13LWR Logging While Retrieving . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-15MAFP Magna-Tector Free Point Indicator . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-10ML Minilog . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-7MLL Micro Laterolog . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-6MRCH Multi-Conductor Releasable Cablehead . . . . . . . . . . . . . . . . . . . . . . . . .7-16MREX MR Explorer . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-17

Service Mnemomic Service Name Section-Page

Alphabetical


Baker Atlas 11-7Service Name and Mnemonic Lists: AlphabeticalServices Catalog Version 2.1; August 2008

Service Mnemomic Service Name Section-Page

MSR Multi-Level Slimhole Receiver . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-10Nautilus Nautilus Extreme HPHT Logging Instruments . . . . . . . . . . . . . . . . . . . . . 8-2NeoTrip One-Trip Perforate and Completion Systems . . . . . . . . . . . . . . . . . . . . . 6-16NFL Nuclear Flolog . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-13PCL Pipe Conveyed Logging . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-3PDK PDK-100 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-4PDP Perforate and Gravel Pack Completion System . . . . . . . . . . . . . . . . . . 6-17PERFFORM Low Debris Perforating Systems . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-7PNHI Pulsed Neutron Holdup Imager . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-14POLARIS Production Optimization Log and Reservoir Information Solutions . . . 4-6PRAL Production Logging Services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-7PRL Pipe Recovery Log . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-7PSI Parallel Perforating System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-19PSW Powered Capstan . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-10PSR PipeSeis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-11 RAL Radial Analysis Bond Log . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-4RCI Reservoir Characterization Instrument . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-3RCOR Rotary Sidewall Coring Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-9RHRA High-Efficiency Flywheels . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-12RLSC High-Performance Tool Positioning . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-12ROLI Roller Assembly . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-12RPM Reservoir Performance Monitor . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-3RWC Surface Remote Hydraulic Wireline Cutter . . . . . . . . . . . . . . . . . . . . . . 7-18RWCC Surface Remote Wireline Clamp and Cutter . . . . . . . . . . . . . . . . . . . . . 7-18SAFP Spring Anchor Free Point Indicator . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-9SBT Segmented Bond Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-3SGS Stackable Gun System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-11SLS Seismic Logging Systems . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-13SON Noise (Sonan) Log . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-17SON/TEMP Noise (Sonan)/Temperature Log . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-14SRPG Surface Readout Pressure Gauge . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-16STAR Water-Based Mud Formation Resistivity Imager . . . . . . . . . . . . . . . . . 1-25STIM Propellant Assisted Perforating Products . . . . . . . . . . . . . . . . . . . . . . . . 6-5SWC Sidewall Corgun . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-10SWVL Swivels . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-13TASMAN Integrated Seismic Navigation System . . . . . . . . . . . . . . . . . . . . . . . . . . 3-14 TEMP Temperature Log . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-18TCP-AOP TCP Azimuthally Oriented Perforating . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-18TDP Pump Down Conveyance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-5TRL Tracerlog . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-13VRT Vertilog Service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-20

VSFusion Borehole Seismic Processing . . . . . . . . . . . . . . . . . . . . . . . . .3-16 WellLink Data Delivery Service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9-2WGI Well Geometry Instrument . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-29WHI Water Holdup Indicator . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-12WTCL Tractor Conveyed Logging . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-4XLD eXtreme Low Debris Perforating Systems . . . . . . . . . . . . . . . . . . . . . . . . 6-6XMAC F1 Cross-Multipole Array Acoustilog F1 . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-14XPLS Predator Low Swell Guns . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-8XSMC High-Strength – Multi-Conductor Cable . . . . . . . . . . . . . . . . . . . . . . . . . .7-9ZDL Compensated Z-Densilog . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-9ZVSP Zero Offset Vertical Seismic Profile . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-4

Baker Atlas11-8 Index

Index


Service Name Section-Page

2-Dimensional VSP (2-D VSP) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-6 3-Dimensional VSP (3-D VSP) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-53D Explorer Induction Logging Service (3DEX Elite) . . . . . . . . . . . . . . . . . . . . . . 1-5Acoustic Cement Bond Log (CBL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-5Acoustic Waveform Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-2Basket Flowmeter (FMBK) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-10Borehole Image Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-7Buried Gun Array . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-12 Cased Hole Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-8Chemical Cutter (CC) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-12Circumferential Borehole Imaging Log (CBIL) . . . . . . . . . . . . . . . . . . . . . . . . . . 1-27Coiled Tubing Conveyed Logging (CTCW) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-5Coiled Tubing Conveyed Perforating (CTCP) . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-15Compensated Neutron (CN) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-10Compensated Z-Densilog (ZDL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-9Continuous Spinner Flowmeter (FMCS) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-8Cross-Multipole Array Acoustilog (XMAC F1) . . . . . . . . . . . . . . . . . . . . . . . . . . 1-14Data Delivery Service (WellLink) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9-2Digital Acoustilog (DAL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-15Digital Magnelog Service (DMAG) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-21Digital Multi-level Downhole Seismic Array (GWV) . . . . . . . . . . . . . . . . . . . . . . 3-9Digital Spectralog (DSL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-12Diplog Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-6Downhole Receiver Array Geochain (GCN) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-8Dual Laterolog (DLL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-4Dynamic Underbalance Optimization Process (DUO) . . . . . . . . . . . . . . . . . . . . . 6-4EARTH Imager . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-26Electro-Magnetic Orienting Perforating (EMO) . . . . . . . . . . . . . . . . . . . . . . . . . 6-14Energy Sources/Source Controllers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-15Extreme HPHT Logging Instruments . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8-2eXtreme Low Debris Perforating Systems (XLD) . . . . . . . . . . . . . . . . . . . . . . . . . 6-6FOCUS Compensated Neutron (F_CN) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-22FOCUS Compensated Z-Densilog (F_ZDL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .1-21FOCUS Digital Acoustilog (F_DAL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-20FOCUS Gamma Ray Log (F_GR) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-23FOCUS High Definition Induction Log (F_HDIL) . . . . . . . . . . . . . . . . . . . . . . . . . .1-19Folding Impeller Flowmeter (FMFI) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-9Free Point Indicator (FPI) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-8Gamma Ray Log (GR) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-11Geomechanics Services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-3GeoWaves (GWV) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-9 Guardian II System (GDN) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-21Hexagonal Diplog (HDIP) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-28High-Definition Induction Log (HDIL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-3High-Efficiency Flywheels (RHRA) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-12

Index

Baker Atlas 11-9IndexServices Catalog Version 2.1; August 2008


High-Performance Tool Positioning (RLSC) . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-12High-Strength – Multi-Conductor Cable (XSMC) . . . . . . . . . . . . . . . . . . . . . . . . 7-9Hole Finders (HFD) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-13Horizontal Oriented Perforating System (HOPS) . . . . . . . . . . . . . . . . . . . . . . . . . 6-9HPHT Logging Instruments (Nautilus) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8-2Hydraulic-Fracture Monitoring . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-7Hydraulic Wireline Jars (EEJ) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-11Hydraulic Wireline Severing Tool (HWST) . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-18Hydrolog (HYDL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-15Imaging Caliper Log (ICL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-22Integrated Borehole Seismic Navigation System (TASMAN) . . . . . . . . . . . . . 3-14 Inter-Gun Automatic Release (IGAR) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-12Jet Cutter (JCS) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-13Knuckle Joints (KNJ) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-13Logging While Retrieving (LWR) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-15Low Debris Perforating Systems (PERFFORM) . . . . . . . . . . . . . . . . . . . . . . . . . . 6-7Magna-Tector Free Point Indicator (MAFP) . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-10Mechanical Wireline Jars (ISJ) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-11Micro Laterolog (MLL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-6Minilog (ML) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-7Model J-Gun Brake (J-GB) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-13MR Explorer (MREX) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-17Multi-Conductor Releasable Cablehead (MRCH) . . . . . . . . . . . . . . . . . . . . . . . 7-16Multi-Level Slimhole Receiver (MSR) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-10 Noise (Sonan) Log (SON) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-17Noise (Sonan)/Temperature Log (SON/TEMP) . . . . . . . . . . . . . . . . . . . . . . . . . . 5-14Nuclear Flolog (NFL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-13Nuclear Fluid Density (FDN) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-11Nuclear Magnetic Resonance Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .10-4Oil-Based Mud Formation Resistivity Imager (EARTH) . . . . . . . . . . . . . . . . . . . 1-26One-Trip Perforate and Completion Systems (NeoTrip) . . . . . . . . . . . . . . . . . . 6-16Parallel Perforating System (PSI) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-19PDK-100 (PDK) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-4Perforate and Gravel Pack Completion System (PDP) . . . . . . . . . . . . . . . . . . . 6-17Perforating Charges . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-3Pipe Conveyed Logging (PCL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-3Pipe Evaluation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-10Pipe Recovery Log (PRL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-7PipeSeis (PSR) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-11 Post-Survey Modeling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-21Powered Capstan (PSW) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-10Predator XP Low Swell Guns (XPLS) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-8Presurvey Modeling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-23Production Log Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10-9Production Logging Services (PRAL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-7

Baker Atlas11-10 Index

Index



Production Optimization Log and Reservoir (POLARIS) . . . . . . . . . . . . . . . . . . . 4-6Propellant Assisted Perforating Products (StimGun) . . . . . . . . . . . . . . . . . . . . . 6-5Pulsed Neutron Holdup Imager (PNHI) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-14Pump Down Conveyance (TDP) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-5Q-Compensating Surface Seismic Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-19Radial Analysis Bond Log (RAL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-4Reservoir Characterization Instrument (RCI) . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-3RCI Multi-tank Carrier . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-8RCI Single-phase Tanks . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-7Reservoir Performance Monitor (RPM) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-3Resistivity Processing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .10-5Risk-Reduction Technologies . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-6Roller Assembly (ROLI) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-12Rotary Sidewall Coring Tool (RCOR) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-9SampleView IB . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-5SampleView IC . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-6Segmented Bond Tool (SBT) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-3Seismic Logging Systems (SLS) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-13 Sidewall Corgun (SWC) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-10Single-Conductor Releasable Tool (ART) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-17Snapshot CT Live Well Deployment System . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-10Special Processing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-20Spring Anchor Free Point Indicator (SAFP) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-9Stackable Gun System (SGS) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-11STAR Imager . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-25StimGun Propellant Assisted Perforating Products . . . . . . . . . . . . . . . . . . . . . . 6-5 Straddle Packer Module . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-4String Shot Backoff (BO) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-11Surface Readout Pressure Gauge (SRPG) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-16Surface Remote Hydraulic Wireline Clamp and Cutter (RWCC) . . . . . . . . . . 7-18Surface Remote Hydraulic Wireline Cutter (RWC) . . . . . . . . . . . . . . . . . . . . . . 7-18Swivels (SWVL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-13TCP Azimuthally Oriented Perforating . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-18Temperature Log (TEMP) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-18Tracerlog (TRL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-13Tractor Conveyed Logging (WTCL) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-4Tubing-Conveyed Dual String Perforating Systems . . . . . . . . . . . . . . . . . . . . . 6-20Velocity Survey . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-3Vertilog Service (VRT) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-20Walkaway VSP . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-5 Water-Based Mud Formation Resistivity Imager (STAR) . . . . . . . . . . . . . . . . . 1-25Water Holdup Indicator (WHI) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-12Well Geometry Instrument (WGI) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-29Well Intervention Modeling Services (CERB) . . . . . . . . . . . . . . . . . . . . . . . . . . . 7-7Zero Offset Vertical Seismic Profile (ZVSP) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-4

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